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Home My WebLink About219-0081. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12958' None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Staff P&A Engineer KRU 3S-08CL1 5876' 8186' 5741' 8186' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8226' MD and 5757' TVD N/A Contact Name: Joey Roth Contact Email: Joey.Roth@conocophillips.com Contact Phone:(907)265-1513 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 219-008 P.O. Box 100360, Anchorage, AK 99510 50-103-20450-60-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst 8237' MD MD 108' 2661' 5848' 108' 4263' 16" 9-5/8" 75' 7"8769' 4234' 8795' Slotted Liner: 10690-11700', 11821-12918' 2-3/8" Slotted Liner: 5861-5866', 5865-5874' Perforation Depth TVD (ft): 10/10/2025 12918'2229' 3-1/2" 5874' Packer: 80-40 Bonded Seal Assmby SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Joey Roth DN: CN=Joey Roth, E=Joey.Roth@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2025.09.30 15:50:26-08'00' Foxit PDF Editor Version: 13.1.6 Joey Roth 325-591 By Grace Christianson at 8:06 am, Oct 01, 2025 DSR-10/2/25A.Dewhurst 01OCT25 June 30, 2026 2161 psi -bjm 10-407 BJM 10/9/25 Attempt to squeeze cement into both 13-08C and 13-08C L1 laterals below retainer. X 10/10/25 Kuparuk River Unit 3S-08C Suspend PTD #: 207-163 Request to Suspend and plug reservoir of 3S-08C prior to full P&A later in the year API #: 50-103-20450-03-00 The 3S-08CL1 was drilled with coil tubing from the C mother bore in 2019. The well has been Shut in since 1/08/2021 and has been identi ed as a P&A candidate, to allow for slot recovery and slot optimization for Coyote Development. The 3S-08 will require rig assisted P&A operations which are currently being developed. Due to 2025 rig schedule constraints, Conoco Phillips would like to plug the producing interval and perform rig less suspension operations on 3S-08C on October 10, 2025: with P&A operations to follow later in the year. Suspension operations will reduce the work scope and timeline tor future P&A operations. The 3S-08C L1 was drilled with Coil from the C mother bore and is completed with 2 3/8 tubing set at 12,918 MD / 5874 TVD. The tubing is set below a Baker HRD ZXP Liner top packer @ 8,188 MD. Per this procedure, suspend operations will be performed by pumping 58 bbl. of 15.8 ppg, Class G cement through a cement retainer above the liner top packer 8170 MD, then placing 1 bbl. on top of the retainer. A tag and pressure test will con rm planned Top of Cement in the tubing @ 8055 MD. Well Status and History: Last MITs :6/28/2025: MIT-T 2500 psi (good test) SBHP: 5/2/2023: 2736 psi @ 5747 TVD. Min ID: 6/28/2025: 2.81 OD run to 8186 wlm. Last Tag: 6/28/2025: Set CA-2 pug in DS nipple @ 8186 wlm 79 bbls cement per Joey Roth email 10/9/25. volume intended to fill both 3S-08C & 3S-08CL1 -bjm Procedure: Slick line / LRS Objective: Drift for cement retainer, perform injectivity tests to con rm adequate rates for cementing operations. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and Pressure Test equipment as required. 3. Drift 3 ½ tubing (2.8 ID) to 8,180 MD (rkb). Note: schematic shows NO-GO at 8186 MD (rkb). 4. Perform Injectivity Test down tubing: pump 20 bbl. diesel, perform step rate injectivity test from 0.5 3 bpm, in ½ bpm increments, up to a maximum pressure of 2500 psi, to ensure adequate rates for cementing operations. Record injectivity test results (Time/Rate/pressure). Discuss results with the well interventions Engineer prior to pumping cement. 5. RDMO Coil Tubing / Cementing: Objective: Place a full column cement plug across the perforations, hesitate & squeeze 5 bbl. cement into the perforations. Plan to place one bbl. cement on top of the cement retainer @ 8170 MD. Cement Volumes (Planned TOC 8,055 MD above Cement Retainer in 3 ½ TBG): 3 1/2 (ID: 2.992) Tubing: 8055 8237MD (182), Volume (1.58 bbl.) 4 ½ (ID: 3.958) Liner: 8237 10702 MD (2465), Volume (37.5 bbl.) 2 3/8 (ID: 1.99) slotted liner: 10689 12918 MD (2229), Volume (8.6 bbl.+ 100% excess = 17.2 bbl.) Total BBL. Cement to pump: 56.2 bbl. + 1bbl (top of retainer) 58 bbl. 6. Ensure an approved Sundry has been received from AOGCC. 7. Contact Cementers a week before the scheduled suspend date, to allow for adequate pilot testing of the P&A cement design. The job is designed for 58 bbl. of 15.8 ppg, Class G cement with gas block additive. 8. Conduct Pre-job Safety Meeting identifying hazards and responsibilities. Inspect wellhead and surrounding pad to identify hazards. 9. RU Coil Tubing Unit and Pressure Test Surface equipment to 3500 psi. 10. Reference the well view tubing schematic and correlate with CCL. +21 bbls = 79 bbls total. See Joey Roth email dated 10/9/25. -bjm 4-1/2" liner from 10702' - 12055' MD to fill liner below whipstock (21 bbls). See See Joey Roth email dated 10/9/25. -bjm 11. RIH w/ cement retainer, taking returns up the CT x Tubing annulus (reverse). Do not Pump while RIH w/ cement retainer. 12. Set the cement retainer 8170 MD, or as deep as the retainer will safely drift. 13. Line up to pump down the CT w/ the CT x tubing annulus closed. 14. Pump 20 bbl. diesel through the retainer to verify proper set and injectivity required for cementing operations (±2 bpm @ 2000 psi). 15. Pump 10 bbl. freshwater spacer 16. Pump 58 bbl. of 15.8ppg Class G Cement through the cement retainer. If squeeze pressure is seen before pumping the total cement volume, stop pumping and begin the next step. 17. Shut down, unsting from retainer. 18. Lay remaining 1 bbl. cement on top of the retainer (1 bbl = 115 ft / bbl., leaving TOC 8055 MD) 19. POOH above TOC. Circulate Coil tubing clean. 20. RDMO 21. WOC (24 hours minimum). 22. Notify the AOGCC Inspector of the timing for the cement plug tag and test 24 hrs. in advance. Slickline / LRS: Objective: State Witness of TOC & MIT-T 23. Conduct a Pre-Job Safety meeting, equipment & pad inspection and hazard identi cation. Tag and Pressure Test must be Witnessed by AOGCC Inspector. 24. RU Slickline and Pressure test equipment to 2000 psi. 25. RIH and tag TOC 8055 MD. Record the depth of tag and pressure test results in Well View. 26. RU LRS and Pressure test equipment to 2000 psi. 27. Perform MIT-T to 1500 psi. 28. Report results and / or issues to the one call well intervention engineer. 29. RDMO. Tubular Detail: Superseded 16" 62.5# H-4 Conductor 108' MD / TVD 3S-08CL1 Plug & Suspend Diagrams (not to scale)/ 9/27/2025 7" LINER TOP PKR 8188' MD Current Completion Proposed Suspension Surface Casing 9 5/8", 40 #, L-80 BTCM Set at 4263' MD / 2611' TVD Intermediate Casing 7", 26.4# L-80 BTCM Set @ 8795' MD / 5848' TVD 4 ½ Liner, 12.6#, L-80 IBTMOD 8188' - 12055' MD Tubing 3.5" 9.3# L80 8rnd EUEM 3S-08CAbandoned4 ½ LinerTubing 3.5" 9.3# L80 8rnd EUEM DS Nipple DS Nipple GLM GLM GLM GLM GLM GLM GLM GLM GLM GLM DS Nipple 3S-08CL1: 2 3/8" slotted/ blank liner TOL:10689' - BOL 12918' MD KOP 10,702' MD 3S-08CAbandoned4 ½ LinerRetainer 3S-08 CL1 PB13S-08 CL1 PB14 ½ LINER TOP PKR 10689' MD Plug Back: 3S-08CL1PB1 TD @ 12903' MD PBTD Top of Cement: 8055' MD Squeeze retainer @ 8170' MD 16" 62.5# H-4 Conductor 108' MD / TVD 3S-08CL1 Plug & Suspend Diagrams (not to scale)/ 9/27/2025 7" LINER TOP PKR 8188' MD Current Completion Proposed Suspension Surface Casing 9 5/8", 40 #, L-80 BTCM Set at 4263' MD / 2611' TVD Intermediate Casing 7", 26.4# L-80 BTCM Set @ 8795' MD / 5848' TVD 4 ½ Liner, 12.6#, L-80 IBTMOD 8188' - 12055' MD Tubing 3.5" 9.3# L80 8rnd EUEM 3S-08CAbandoned4 ½ LinerTubing 3.5" 9.3# L80 8rnd EUEM DS Nipple DS Nipple GLM GLM GLM GLM GLM GLM GLM GLM GLM GLM DS Nipple 3S-08CL1: 2 3/8" slotted/ blank liner TOL:10689' - BOL 12918' MD KOP 10,702' MD 3S-08CAbandoned4 ½ LinerRetainer 3S-08 CL1 PB13S-08 CL1 PB14 ½ LINER TOP PKR 10689' MD Plug Back: 3S-08CL1PB1 TD @ 12903' MD PBTD Top of Cement: 8055' MD Squeeze retainer @ 8170' MD Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTU - RKB 12,055.0 3S-08C 4/27/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set plug 3S-08C 6/28/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: UNABLE TO CIRCULATE EITHER DIRECTION WHEN GLM @ 8138' RKB HAS OPEN POCKET 5/7/2018 zembaej NOTE: ***WARNING*** LINER TOP PACKER IN IA - DO NOT EXCEED 3000 psi 1/22/2008 triplwj NOTE: WELL SIDETRACKED 1/21/2008 1/21/2008 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 33.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.70 28.7 4,263.0 2,661.1 40.00 L-80 BTCM INTERMEDIATE 7 6.28 26.5 8,795.0 5,847.7 26.40 L-80 BTCM LINER 4 1/2 3.96 8,188.2 12,055.0 12.60 L80 IBTMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.8 Set Depth 8,237.0 Set Depth 5,760.9 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd-Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.8 22.8 0.00 HANGER 10.850 3.5" Gen V Tbg Hanger EUE 8rd & pup ( Hgr .75' - Pup 3.65') FMC 2.992 502.1 500.4 9.39 NIPPLE 5.220 3.5" "DS" Nipple w/2.875" NO-GO profile EUE 8rd-M Camco 2.875 4,588.9 2,816.4 58.04 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 5,773.9 3,701.8 23.14 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 6,645.8 4,505.3 23.94 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 7,360.4 5,146.8 29.82 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 8,138.1 5,719.3 60.43 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 8,186.4 5,741.4 65.07 NIPPLE 4.520 3.5" "DS" Nipple w/2.812" NO-GO profile EUE 8 rd-M Camco 2.812 8,195.6 5,745.2 65.92 LOCATOR 5.000 5" Locator Sub 2.992 8,225.5 5,756.8 68.70 SEAL ASSY 3.980 80-40 Bonded Seal assembly 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,186.0 5,741.3 65.03 TUBING PLUG 2.81" CA-2 Plug (OAL = 28") 6/28/2025 0.000 10,689.0 5,861.0 91.20 LINER TOP CTD 2/3" Liner top. Note: Liner top @ 90 degrees deviation. 2/10/2019 1.995 10,700.0 5,860.7 91.43 WHIPSTOCK Baker Gen 2 Delta whipstock, 12.98' OAL. Set by CDR3. 2/3/2019 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,588.9 2,816.4 58.04 1 Gas Lift OV RK 1 1/2 0.0 11/2/2023 0.025 5,773.9 3,701.8 23.14 2 Gas Lift DMY RK 1 1/2 0.0 5/3/2023 0.000 6,645.8 4,505.3 23.94 3 Gas Lift DMY RK 1 1/2 0.0 1/20/2008 0.000 7,360.4 5,146.8 29.82 4 Gas Lift DMY RK 1 1/2 0.0 11/2/2023 0.000 8,138.1 5,719.3 60.43 5 Gas Lift DMY RK 1 1/2 0.0 5/12/2018 Notes 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,188.2 5,742.2 65.23 PACKER 5.960 5" x 7" "HRD" ZXP Liner top Pkr w/10.60 ext TOL ==> 5.250 8,206.8 5,749.8 66.97 NIPPLE 5.570 "RS" Packoff seal nipple jt w/TKC couplings(5.57" OD) 4.250 8,240.6 5,762.1 69.93 XO BUSHING 5.600 XO Bushing 5" BTC x 4 1/2" IBT (Max OD 5.6) 3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,750.0 8,790.0 5,843.9 5,847.3 C-4, 3S-08C 9/3/2009 6.0 APERF 2.5" HES Millenium gun, 60° ph 9,322.0 9,328.0 5,843.5 5,843.3 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/6½" holes per pup 9,543.0 9,548.0 5,846.8 5,847.0 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,011.0 10,016.0 5,868.5 5,868.5 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,171.0 10,177.0 5,864.6 5,864.4 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,363.0 10,368.0 5,862.7 5,862.6 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,524.0 10,528.0 5,861.9 5,861.9 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,715.0 10,720.0 5,860.3 5,860.2 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup HORIZONTAL, 3S-08C, 9/30/2025 3:01:46 PM Vertical schematic (actual) LINER; 8,188.2-12,055.0 PERFP; 11,997.0-12,001.0 PERFP; 11,524.0-11,530.0 PERFP; 11,310.0-11,315.0 PERFP; 10,997.0-11,002.0 PERFP; 10,715.0-10,720.0 WHIPSTOCK; 10,700.0 LINER TOP; 10,689.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 Acid Wash; 9,322.0 PERFP; 10,011.0-10,016.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 TUBING PLUG; 8,186.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD KB-Grd (ft) 33.30 RR Date 1/21/2008 Other Elev 3S-08C ... TD Act Btm (ftKB) 12,055.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045003 Wellbore Status PROD Max Angle & MD Incl (°) 93.43 MD (ftKB) 9,173.50 WELLNAME WELLBORE3S-08C Annotation Last WO: End DateH2S (ppm) 75 Date 5/7/2023 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,997.0 11,002.0 5,863.1 5,863.4 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,310.0 11,315.0 5,860.5 5,860.5 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,524.0 11,530.0 5,855.9 5,855.6 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,997.0 12,001.0 5,869.6 5,869.8 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,322.0 11,000.0 1 Acid Wash 5/14/2009 0.0 0.00 0.00 HORIZONTAL, 3S-08C, 9/30/2025 3:01:47 PM Vertical schematic (actual) LINER; 8,188.2-12,055.0 PERFP; 11,997.0-12,001.0 PERFP; 11,524.0-11,530.0 PERFP; 11,310.0-11,315.0 PERFP; 10,997.0-11,002.0 PERFP; 10,715.0-10,720.0 WHIPSTOCK; 10,700.0 LINER TOP; 10,689.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 Acid Wash; 9,322.0 PERFP; 10,011.0-10,016.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 TUBING PLUG; 8,186.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD 3S-08C ... WELLNAME WELLBORE3S-08C Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 3S-08CL1 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE: Halliburton Swell Packer at 11,767'MD (min ID 1.686") 3/4/2019 jennalt NOTE: 1.781" RN Profile @ 11,732'MD - No-go is 1.640" 3/4/2019 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CL1 LATERAL 2 3/8 1.99 10,689.0 12,918.0 5,874.3 4.60 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,689.0 5,861.0 91.20 Shorty Deployment Sleeve 0.000 Shorty Deployment Sleeve 0.000 11,731.5 5,866.1 90.14 NIPPLE RN Nipple 11,764.4 5,866.0 90.32 XO 2.375 XO (2-3/8" STL Box x 2-1/16" HYD 511 Pin) 1.992 11,767.4 5,866.0 90.39 PACKER Halliburton Swell Packer & Pups 11,790.1 5,865.7 90.92 XO 2.375 XO (2-1/16" HYD 511 BOX x 2- 3/8" STL Pin ) 1.992 11,884.1 5,865.7 89.16 Shorty Deployment Sleeve 0.000 Shorty Deployment Sleeve 0.000 HORIZONTAL, 3S-08CL1, 9/30/2025 3:01:47 PM Vertical schematic (actual) CL1 LATERAL; 10,689.0- 12,918.0 LINER; 8,188.2-12,055.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 PERFP; 10,011.0-10,016.0 Acid Wash; 9,322.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 TUBING PLUG; 8,186.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD KB-Grd (ft) 33.30 RR Date 1/21/2008 Other Elev 3S-08CL1 ... TD Act Btm (ftKB) 12,958.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045060 Wellbore Status PROD Max Angle & MD Incl (°) 93.43 MD (ftKB) 9,173.49 WELLNAME WELLBORE3S-08C Annotation Last WO: End DateH2S (ppm) 75 Date 5/7/2023 Comment DATA SUBMITTAL COMPLIANCE REPORT 5/13/2019 Permit to Drill 2190080 Well Name/No. KUPARUK RIV UNIT 3S-08CL1 ?B 1. Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20450-60-00 MD 12958 TVD 5876 Completion Date 2/10/2019 Completion Status 1-0I1- Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No ✓ Samples / ✓ No ., Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval CHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30438 Digital Data 8268 12903 3/12/2019 Electronic Data Set, Filename: 3S-08CL1 GAMMA RES.Ias ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 21VID Final Log.cgm ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 51VID Final Log.cgm ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 5TVDSS Final i ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 2MD Final Log.pdf ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 51VID Final Log.pdf ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 5TVDSS Final Log.pdf I ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 EOW - NAD27.pdf ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 EOW - NAD27.txt ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 Final Surveys 12958 TD.csv ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 Final Surveys 12958 TD.xlsx ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 Survey Listing.bd ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 Surveys.bd ED C 30438 Digital Data 3/12/2019 Electronic File: 3S- 08CL 1 _25_tapescan_BH I_CTK.txt ED C 30438 Digital Data 3/12/2019 Electronic File: 3S- 08CL1_5_tapescan_BHI _CTK.txt ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1_output.tap ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 21VID Final Log.tif ED C 30438 Digital Data 3/12/2019 Electronic File: 3S-08CL1 51VID Final Log.tif AOGCC Pagel of 4 Monday, May 13, 2019 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2019 Permit to Drill 2190080 Well Name/No. KUPARUK RIV UNIT 3S-08CL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20450-60-00 MD 12958 TVD 5876 Completion Date 2/10/2019 Completion Status 1 -OIL ED C 30438 Digital Data LOG HEADERS ED C 30438 Log Header Scans 0 0 ED C 30439 Log Header Scans 0 0 ED C 30439 Digital Data 8268 12903 ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data ED C 30439 Digital Data Current Status 1 -OIL UIC No 3/12/2019 Electronic File: 3S-08CL1 5TVDSS Final Log.tif AOG('C Page 2 of 4 Monday, May 13, 2019 2190080 KUPARUK RIV UNIT 3S-08CL1 LOG HEADERS 2190080 KUPARUK RIV UNIT 3S-08CL1PB1 LOG HEADERS 3/12/2019 Electronic Data Set, Filename: 3S-08CL1PB1 GAMMA RES.Ias 3/12/2019 Electronic File: 3S-08CL1 PBI 2MD Final Log.cgm 3/12/2019 Electronic File: 3S-08CL1 PB1 51VID Final Log.cgm 3/12/2019 Electronic File: 3S-08CL1 PB1 5TVDSS Final Log.cgm 3/12/2019 Electronic File: 3S-08CL1 PB1 21VID Final Log.pdf 3/12/2019 Electronic File: 3S-08CL1 PB1 51VID Final Log.pdf 3/12/2019 Electronic File: 3S-08CL1PB1 5TVDSS Final Log.pdf 3/12/2019 Electronic File: 3S-08CL1PB1 EOW - NAD27.pdf 3/12/2019 Electronic File: 3S-08CL1PB1 EOW - NAD27.txt 3/12/2019 Electronic File: 3S-08CL1PB1 Final Surveys 12903 uncorrected.csv 3/12/2019 Electronic File: 3S-08CL1PB1 Final Surveys 12903 uncorrected.xlsx 3/12/2019 Electronic File: 3S-08CL1PB1 Survey Listing.txt 3/12/2019 Electronic File:3S-08CL1PB1 Surveys.txt 3/12/2019 Electronic File: 3S- 08CL1 PB1_25_tapescan_BHI_CTK.txt 3/12/2019 Electronic File: 3S- 08CL1 PB1_5_tapescan_BHI_CTK.txt 3/12/2019 Electronic File:3S-08CL1 PB 1_output.tap 3/12/2019 Electronic File: 3S-08CL1 PB1 21VID Final LogAlf 3/12/2019 Electronic File: 3S-08CL1 PB1 51VID Final Log.tif 3/12/2019 Electronic File: 3S-08CL1PB1 5TVDSS Final Log.tif AOG('C Page 2 of 4 Monday, May 13, 2019 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2019 Permit to Drill 2190080 Well Name/No. KUPARUK RIV UNIT 3S-08CL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20450-60-00 MD 12958 TVD 5876 Completion Date 2/10/2019 Completion Status 1-0IL ED C 30469 Digital Data ED C 30469 Digital Data ED C 30469 Digital Data ED C 30469 Digital Data ED C 30469 Log Header Scans ED C 30470 Log Header Scans ED C 30470 Digital Data ED C 30470 Digital Data ED C 30470 Digital Data ED C 30470 Digital Data Well Cores/Samples Information Name Interval Start Stop INFORMATION RECEIVED 3/19/2019 Completion Report 0 Directional / Inclination Data ! Y 1 Production Test InformatioNA Mechanical Integrity Test Information Y // NA Geologic Markers/Tops Sy Daily Operations Summary 0 COMPLIANCE HISTORY Completion Date: Release Date: Description AOGCC 2/10/2019 1/18/2019 Date Comments Page 3 of 4 0 0 0 0 Current Status 1 -OIL UIC No 3/19/2019 Electronic File: 3S-08CL1 EOW - NAD27.pdf 3/19/2019 Electronic File: 3S-08CL1 EOW - NAD27.txt 3/19/2019 Electronic File: 3S-08CL1 EOW - NAD83.pdf 3/19/2019 Electronic File: 3S-08CL1 EOW - NAD83.txt 2190080 KUPARUK RIV UNIT 3S-08CL1 LOG HEADERS 2190080 KUPARUK RIV UNIT 3S-08CL1PB1 LOG HEADERS 3/19/2019 Electronic File: 3S-08CLI PBI EOW - NAD27.pdf 3/19/2019 Electronic File: 3S-08CL1 PBI EOW - NAD27.txt 3/19/2019 Electronic File:3S-08CLI PBI EOW -NAD83.pdf 3/19/2019 Electronic File: 3S-08CL1 PB1 EOW-NAD83.txt Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y 6 Core Chips y&) Composite Logs, Image, Data Files ) Core Photographs Y /6 Cuttings Samples Y NA Laboratory Analyses Y / Monday, May 13, 2019 DATA SUBMITTAL COMPLIANCE REPORT 511 312 01 9 Permit to Drill 2190080 Well Name/No. KUPARUK RIV UNIT 3S-08CL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20450-60-00 MD 12958 TVD 5876 Completion Date 2/10/2019 Comments: Compliance Reviewed By: Completion Status 1-0I1 Current Status 1-0I1- UIC No Date AOGC(' Page 4 of 4 Monday, May 13, 2019 rilt"MEIVED €=1AN 19 2019 b:�GCC BATER a GE company Date: March 18, 2019 Abby Bell AOGCC 333 West 71^ Ave, Suite 100 Anchorage, Alaska 99501 21 9008 30469 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 3S-08CU 35-08CUPB1 (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3S Pad 3S-08CL1 50-103-20450-60 Baker Hughes INTEQ Definitive Survey Report 07 March, 2019 BAT(ER r jUGHES a GE company 219008 30469 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3S Pad MD Reference: Well: 3S-08 North Reference: Wellbore: 3S -08C Survey Calculation Method: Design: 3S-08CL1 Database: Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3S-08 -� Well Position +N/ -S 0.00 usft Northing: +EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore - 3S-08CL1 Magnetics Model Name Sample Date BGGM2018 2/6/2019 Design 3S-08CL1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 27.50 Well 35-08 38-08C Q 55.20usft (Doyon 141) 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,993,923.52usft 476,305.45usft 27.50usft Latitude: Longitude: Ground Level: BA UG ES 70" 23'40.307 N 150° 11'34.034 W 27.70 usft Declination Dip Angle Field Strength Inn 3 i 16.63 80.87 57,420 j Tie On Depth: 12,012.83 +N/ -S +E/ -W (usft) (usft) 0.00 0.00 3/7!2019 9:46:54AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips a ERWHES 0 I� ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Local Co-ordinate Reference: Well 3S-08 7 Project: Kuparuk River Unit TVD Reference: 3S -08C @ 55.20usft (Doyon 141) Vertical Site: Kuparuk 3S Pad Inc MD Reference: 3S -08C @ 55.20usft (Doyon 141) TVDSS +N/ -S Well: 35-08 Easting North Reference: True Wellbore: 3S -08C (°) Survey Calculation Method: Minimum Curvature (usft) (usft) Design: 3S-08CL1 (°1100') Database: EDT 14 Alaska Production Annotation (ft) i (ft) (ft) 12,012.83 Survey Program 311.24 Date 5,813.02 3,999.58 35.77 5,989,924.63 From To -1,925.51 MWD(6) TIP Survey Survey (usft) (usft) Survey (wellbore) Tool Name Description StartDate End Date 85.90 85.90 35-08 CB -GYRO -SS (35-08) CB -GYRO -SS Camera based gyro single shot 2/25/2003 2/25/2003 194.59 4,207.48 35-08 IIFR(35-08) MWD-IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 2/25/2003 3/6/2003 4,262.50 8,780.39 3S -08C IIFR+MS+SAG Halliburton (35-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/14/2007 12/17/2007 8,823.57 10,650.01 3S -08C IIFR+MS(3S-OBC) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/14/2007 1/21/2008 10,702.00 10,840.20 3S-08CL1PB1 MWD -INC (3S-08CL1PB1 MWD -INC -ONLY MWD -INC -ONLY -FILLER 2/5/2019 2/5/2019 10,875.96 12,012.83 3S-08CLIPBI MWD(3S-08CL1 Pal) MWD MWD -Standard 2/6/2019 2/6/2019 12,028.00 12,914.38 3S-08CL1(3S-08CL1) MWD MWD -Standard 2/7/2019 2/7/2019 Survey 3/72019 9:46:54AM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/•W Northing Easting DLS Sectlon (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) i (ft) (ft) 12,012.83 89.79 311.24 5,868.22 5,813.02 3,999.58 35.77 5,989,924.63 476,207.02 7.36 -1,925.51 MWD(6) TIP 12,028.00 90.20 311.80 5,%8.23 5,813.03 3,989.53 -97.12 5,989,934.72 476,195.69 4.58 -1,910.65 MWD (7) KOP 12,060.64 92.00 321.11 5,187.60 5,812.40 -3,965.90 -119.58 5,989,958.41 476,173.31 29.05 -1,879.39 MWD (7) 12,085.40 87.88 323.17 5,867.62 5,812.42 3,946.36 -13477 5,989,978.00 476,158.18 18.60 -1,856.46 MWD (7) 12,120.67 89.11 332.43 5,868.55 5,813,35 -3,916.55 -153.54 5,990,00]86 476,139.51 26.48 -1,825.31 MWD(7) 12,150.72 88.77 341.83 5,869.11 5,813.91 -3,888.90 -165.20 5,990,035.55 476,127.94 31.30 -1,801.38 MWD (7) 12,179.89 89.17 350.78 5,869.63 5,814.43 -3,860.59 -172.10 5,990,063.87 476,121.13 30.71 -1,781.25 MWD (7) 12,210.22 88.89 355.42 5,870.15 5,814.95 -3,830.50 -175.74 5,990,093.98 476,117.58 15.32 -1,763.05 MWD(7) 12,242.90 89.02 352.64 5,870.74 5,815.54 -3,798.00 -179.14 5,990,126.48 476,114.29 8.51 -1,743.86 MWD (7) 12,272.60 88.59 350.82 5,871.36 5,816.16 -3,768.62 -183.41 5,990,155.88 476,110.11 6.30 -1,725.47 MWD (7) 12,302.63 88.71 34657 5,872.07 5,816.87 -3,739.08 -188.78 5,990, 185 43 476,109.84 7.50 -1,706.05 MM (7) 12,332.57 90.06 347.26 5,872.39 5,817.19 3,7G9.81 -195.05 5,990,21412 476,098.66 6.28 -1,685.99 MWD (7) 12,362.56 90.25 345.55 5,872.31 5,817.11 -3,680.66 -202.10 5,990,24388 476,091.71 5.74 -1,665.31 MWD(7) 12,392.54 90.34 343.57 5,872.16 5,816.96 -3,651.77 -210.08 5,990,272.80 476,083.82 6.61 -1,643.95 MWD (7) 12,422.45 89.66 340.94 5,872.16 5,816.96 3,62328 -21920 5,990,301.31 476,07479 9.08 -1,621.81 MWD (7) 12,452.54 90.21 337.96 5,872.19 5,81699 -3,595.11 -229.76 5,990,329.51 476,064.32 1007 -1,598.58 MWD (7) 3/72019 9:46:54AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips B ER UGHES ConocoPhillips Definitive Survey Report liq, w� Company: Project: Site: Well: Wellborn: Design: Survey ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3S Pad 3S-08 3S -08C 3S-O8CL1 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 35-08 3S -08C @ 55.20usft (Doyon 141) 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature EDT 14 Alaska Production Annotation 3172019 9:46:54AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) Plow) Survey Tool Name (ft) (ft) (ft) 12,48180 8994 335.32 5,872.15 5,816.95 -3,566.25 -241.35 5,990,356.41 476,052.81 9.07 -1,575.10 MWD (7) 12,512.22 89.85 331.82 5,872.21 5,81781 -3,541.01 -254.90 5,990,383.68 476,039.36 11.51 -1,549.76 MWD(7) 12,542.45 89.08 327.46 5,872.49 5,817.29 -3,514.94 -270.17 5,990,40981 476,024.17 14.65 -1,52349 MWD (7) 12,571.84 89.36 324.63 5,872.89 5,817.69 3,49056 -286.58 5,990,43423 476,007.83 9.68 -1497.09 MWD (7) 12,601.26 89.79 322.03 5,873.11 5,817.91 -3,466.97 -304.15 5,990,457.88 475,990.34 8.96 -1,470.08 MWD(7) 12,630.36 90.52 320.37 5,873.03 5,817.83 -3,444.29 -322.38 5,990,480.61 475,972.18 6.23 -1,442.95 MW (7) 12,659.82 90.88 317.88 5,872.68 5,817.48 -3,422.02 -391 66 5,990,502.94 475,952.98 8.53 -1,415.12 MWD (7) 12,690.29 90.71 31544 5,872.26 5,817.06 -3,399.86 -362.57 5,990,525.16 475,932.14 8.02 -1,385.94 MWD(7) 12,721.15 90.52 313.48 5,871.93 5,816.73 -3,378.25 -384.59 5,990,546.84 475,910.19 6.38 -1356.06 MWD (7) 12,749.66 90.58 311.57 5,871.65 5,816.45 -3,358.98 405.60 5,990,566.18 475,889.24 6.70 -1,328.23 MWD (7) 12,780.34 91.51 310.16 5,87189 5,815.89 -3,338.91 428.80 5,990,586.32 475,866.11 5.50 -1,298.10 MWD (7) 12,810.33 90.52 308.67 5,870.56 5,815.36 -3,319.87 -451.96 5,990,605.43 475,843.01 5.96 -1,268.52 MWD(7) 12,83990 89.29 307.69 5,870.61 5,815.41 -3,301.60 -475.21 5,990,623.78 475,819.83 5.32 -1,239.26 MWD (7) 12,869.54 86.84 307.08 5,87161 5,816A1 -3,283.61 -498.74 5,990,641.83 475,796.35 8.52 -1,209.88 MWD (7) 12,900.98 86.62 304.55 5,87341 5,818.21 3,265.24 -524.19 5,990,660.28 475,770.96 8.06 -1,178.66 MWD (7) 12,914.38 87.18 303.03 5,874.13 5,818.93 -3,25280 -535.31 5,990,667.75 475,759.87 12.07 -1,165.31 MWD(7) 12,958.00 87.18 303.03 5,876.28 5,821.08 -3,234.06 -571.84 5,990,691.61 475,723.42 0.00 -1,121.80 PROJECTED to TD Annotation 3172019 9:46:54AM Page 4 COMPASS 5000.14 Build 85D FEIVED i I iAi� 5 g 20119 b`"W 4 CCC ER BAI-UHES a GE company Date: March 18, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 21 9008 30 47 0 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 35-OSCL1 35-OSCLIPBI (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey. FinchpBakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3S Pad 3S-08CL1PB1 50-103-20450-70 Baker Hughes INTEQ Definitive Survey Report 07 March, 2019 BAT(ER UGHES a GE company 219008 30470 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuperuk 38 Pad MD Reference: Well: 3S-08 North Reference: Wellbore: 38 -OBC Survey Calculation Method: Design: 3S-O8CL1 PB1 Database: Project Kuparuk River Unit, North Slope Alaska, United States Design Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Vertical Section: Map Zone: Alaska Zone 04 57,414 i Well 35-08 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3S-08CL1PB1 Magnetics Model Name �'--_ BGGM2018 Design 3S-08CL1PB1 Audit Notes: 2770 usft ! Version: 1.0 Vertical Section: (nT) Phase: ACTUAL Depth From (TMD) (Usk) 27 50 Sample Date 4/1/2019 Well 35-08 3S -08C @ 55.20usft (Doyon 141) 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,993,923.52 usft 476,305.45usft 27.50 usft Declination 1°) 16 55 Tie On Depth: 10,650.01 +N/ -S +E/ -W (usft) (usft) 000 000 �ER CA F WHES Latitude: 70' 23'40.307 N Longitude: 150° 11'34.034 W Ground Level: 2770 usft ! Dip Angle Field Strength 1°) (nT) 80.87 57,414 i _.._ i Direction l°1 300.00 3/12019 9:44:55AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3S Pad Well: 35-08 Wellborn: 3S -08C Design: 3S-08CL1PB1 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3S-08 3S -OBC @ 55.20usft(Doyon 141) 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature EDT 14 Alaska Production . Survey Program Data .ww @t From To Survey Survey i (usft) (usft) Survey (Wellbore) Tool Name Description Start Data End Data Ci 85.90 85.90 3S-08 CB -GYRO -SS (3S-08) CB -GYRO -SS Camera based gyro single shot 2/25/2003 2/25/2003 194,59 I 4,207.48 3S-08 IIFR (3S-08) MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/25/2003 3/6/2003 4,262.50 8,760.39 35-08C IIFR+MS+SAG Halliburton (35-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 72/14/2007 12/17/2007 8,823.57 10,650.01 3S -08C IIFR+MS(3S-08C) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 12/14/2007 1/21/2008 10,702.00 10,840.20 3S-08CL1PB1 MWD -INC (3S-08CL1PB1 MWD -INC -ONLY MWD -INC -ONLY -FILLER 2/5/2019 2/5/2019 10,675.96 12,855.51 3S-08CL1 PB1 MWD(3S-08CL1 PB1) MWD MWD -Standard 2/6/2019 2/6/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section Waft) (0) 11 Waft) (usft) (usft). ' (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 10,650.01 90.41 241.87 5,861.55 5,806.35 4,267,65 1,154.47 5,989,652.66 477,446.28 4.91 -3,133.63 MWD -INC -ONLY (5) TIP 10,702.00 91.46 23941 5,860.70 5,805.50 4,293.13 1,109.17 5,989,627.32 477,400.90 5.14 -3,107.14 MWD-INC_ONLY (5) KOP 10,720.24 88.66 241.67 5,860.65 5,805.45 4,302.10 1,00.29 5,989,61640 477,384.99 18.89 -3,097,87 MWD -INC _ONLY (5) Interpolated Azimuth i 10,750.26 90.95 244.89 5,860.70 5,805.50 4,31560 1,066.48 5,989,604.99 477,358.14 12.79 -3,081.40 MWD-INC_ONLY (5) Interpolated Azimuth 10,780.78 88.47 248.16 5,860.86 5,805.66 4,327.75 1,038.50 5,989,592.93 477,330.12 13.45 -3,063.24 MWD -INC _ONLY (5) Interpolated Azimuth E 10,810.81 89.30 251.37 5,861.44 5.803 24 4,338.13 1,010.33 5,989,582.64 477,301,92 11.04 -3,044.04 MWD-INC_ONLY (5) Interpolated Azimuth i 10,840.20 89.63 254.52 5,861.71 5,606.51 4,346.75 982.24 5,989,574.11 477,273.81 10.78 -3,024.02 MWD -INC ONLY(5) Interpolated Azimuth i 10,875.96 90.25 258.35 5,861.75 5,806.55 4,355.14 947.48 5,989,565.83 477,239.03 10.85 -2,998.11 MWD(6) 10,910.44 90.80 261.47 5,861,44 5,80.24 4,361.18 913.54 5,989,559.90 477,205.07 9.19 -2,971.74 MWD (6) 10,940.21 8969 264A5 5,01.31 5,8w 11 4,364.93 884.01 5,989,556.24 477,175.53 9.43 -2,948.04 MM (6) 10,95963 89.82 264.38 5,01.39 5,805 19 4,366.89 864.69 5,989,554.35 477,15621 1.83 -2,932.29 MWD (6) 10,997.04 8972 20.89 5,861.54 5,80.34 4,369.73 827.39 5,989,551.62 477,118.90 6.71 -2,901.41 MWD (6) 11,029.49 86.16 266.97 5,86271 5,80].51 -0,371.47 795.01 5,989,549.99 477,086.52 1097 -2,874.24 MWD (6) 11,060.60 87.15 26964 5,864.52 5,809.32 4,372.39 763.97 5,989,549.17 477,05548 9.14 -2,847.81 MWD(6) 11,091.52 87.61 266.90 5,865.94 5,810.74 4,373.32 733.10 5,989,54833 477,02461 8.98 -2,821.55 MWD(6) $ ! 11,119.80 91.04 268.07 5,686.27 5,811.07 -0,374.56 704.86 5,989,547.18 476,90.37 12.81 -2,797.70 MWD (6) f 11,150.00 9064 270.51 5,05.83 5,810.63 4,374.94 674.66 5,989,546.90 476,966.18 8.19 -2,771.74 MWD (6) { 3/7/2019 9:44:554M Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Definitive Survey ReportuDNws Company: Project: Site: Well: Wellbore: Design: ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3S Pad 35-08 3S -08C 3S-08CL1 PB1 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 35-08 3S -08C @ 55.20usft (Doyon 141) 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature EDT 14 Alaska Production --------.... ..__._._ , ; Survey Map Map Vertical MD Inc Azi TVD TVDSS +W-5 +E/ -W DLS Northing Easting Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) 11,180.32 90.71 274.86 5,865.47 5,810.27 4,373.52 644.39 5,989,548.42 476,935.91 1435 -2,744.81 MWD (6) 11,209.64 90.89 277.60 5,865.06 5,809.86 4,370.33 615.25 5,989,551.69 476,906.78 9.36 -2,717.99 MWD(6) 11,239.70 9021 278.35 5,864.77 5,809.57 4,366.16 58548 5,989,555.96 476,877.03 3.37 -2,690.12 MWD(6) 11,269.57 8991 280.31 5,864]4 5,809.54 4,361.32 556.00 5,989,560.89 476,847.57 664 -2,662.18 MW) (6) 11,303.43 8979 282.94 5,864.83 5,80963 4,354.50 522.84 5,989,567.82 476,814.44 T78 -2,630.04 MWD (6) 11,329.51 89.85 285.07 5,864.91 5,809.71 4,348.19 497.54 5,989,574.21 476,789.16 8.17 -2,604.98 MWD (6) 11,361.98 89.97 288.64 5,864.96 5,809.76 4,33818 466.47 5,989,58372 476,758.12 11.00 -2,573.36 MWD (6) 11,389.64 89.42 289.32 5,865.11 5,809.91 3,32978 44031 5,989,59280 476,731.99 3.16 -2,546.21 MWD (6) 11,42065 89.W 293.40 5,865.30 5,810.10 4,31849 411.44 5.989,604.18 476,703.16 13.24 -2,515.56 MWD (6) 11,445.12 89.88 294.97 5,865.35 5,810.15 4,308.46 389.12 5,989,61427 476,680.87 6.42 -2,491.22 MWD (6) 11,475.01 8945 297.17 5,865.53 5,810.33 4,295.33 362.27 5,989,627.49 476,654.07 7.50 -2,461.40 MWD (6) 11,505.29 89.36 298.86 5,865.84 5,810.64 3,281.11 335.54 5,989,641.80 476,627.39 559 -2,431.14 MWD (6) 11,540.45 88.74 30086 5,866.42 5,811.22 4,263.61 305.06 5,989,65939 476,596.96 5.95 -2,395.99 MWD(6) 11,570.42 89.72 302.81 5,866.83 5,811.63 4,247.80 279.60 5,969,67528 476,571.56 7.28 -2,366.04 MWD (6) ( 11,600.64 89.72 302.30 5,866.97 5,811.77 4,231.54 254.13 5,989,691.62 476,546.14 1.69 -2,335.85 MM (6) 11,631.96 89.82 301.19 5,867.10 5,811.90 4,215.06 227.49 5,989,708.18 476,519.56 3,56 -2,304.54 MWD (6) 11,661.66 90.15 301.21 5,867.11 5,811.91 4,199.67 202.09 5,989,72364 476,494.21 1.11 -2,274.85 MWD (6) 11,692.12 91.63 298.42 5,866.63 5,811.43 -0,184.53 175.67 5,989,738.87 476,467.84 10.37 -2,244.40 MWD (6) 11,724.50 90.12 301.10 5,866.14 5,810.94 4,168.46 147.55 5,989,755.02 476,439.79 9.50 -2,212.03 MM (6) 11,759.51 9021 303.10 5,866.04 5,810.84 4,149.86 117.91 5,989,773.72 476,410.19 5.72 -2,177,04 MWD (6) 11,795.35 91.04 30340 5,865.65 5,810.45 4,130.21 87.93 5,989,793.47 476,380.28 2.46 -2,141.25 MWp (6) { 11,830.73 8915 305.50 5,865.40 5,810.20 4,110.20 58.77 5,989,813.55 476,351.18 6.97 -2,105.99 MWD(6) 11,869.48 89.82 307.09 5,E65.53 5,810.33 4,090.22 31.56 5,989,833.63 476,324.05 4.72 -2,072.45 MWD(6) j 11,891.91 88.90 305.33 5,86584 5,81064 -0,074.02 9.44 5,989,849.90 476,301.97 7.24 -2,045.18 MWD (6) tl 11,920.16 Be'" 307.07 5,866.49 5,81129 4,05234 -13.35 5,98986565 476,279.24 6.37 -2,017.10 MWD (6) 11,952.48 88.07 307.65 5,867.48 5,812.28 4,037.73 -39.03 5,989,88633 476,253.63 2.15 -1,985.07 MWD (6) 11,980.92 89.60 308.90 5,868.05 5,812.85 4,020.12 61.35 5,989,904.01 476,231.37 6.92 -1,956.93 MWD (6) 12,01263 89.79 311.24 5,868.22 5,813.02 -3,999.58 -85.77 5,989,924.63 476,207.02 7.36 4,925.51 MWD(6) 12,040.91 90.55 312.28 5,868.14 5,812.94 -3,980.88 -106.71 5,989,943.39 476,186.13 4.59 -1,898.02 MWD (6) 12,071.03 90.98 315.04 5,86774 5,812.54 -3960.09 -12850 5SB996425 476,164.41 9.27 -1,868.76 MWD(6) 12.10063 90.18 315.29 5,867.44 5,812.24 -3,939.10 -149.37 5,989,965.30 476.14361 2.83 -1.840.19 MWD (6) 3/7/2019 9:44:55AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips Alaska Inc Kuparuk Protech Kuparuk River Unit Site: Kuparuk 3S Pad Well: 3S-08 Wellbore: 3S -08C Design: 3S-08CL1PB1 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: M Well 35 -08 3S -08C @ 55.20usft (Doyon 141) 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature EDT 14 Alaska Production UA(ER UGHES -- Survey Map Map Vertical MD Inc Azi TVD NDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100•) Survey Tool Name Annotation (ft) (ft) (ft) 12,130.91 68.77 316.26 5,867.72 5,812.52 -3,91740 -17048 5,990,007.07 476,122.57 5.65 -1,811,06 MWD (6) 12,160.94 8883 31662 5,868.35 5,813.15 -3,895.65 -191.17 5,990,028.89 476,101.95 1.22 .1,782.26 MWD (6) II{ 12,190.99 89.14 317.43 5,868.88 5,813.68 .3,873.66 .211.66 5,990,050.93 476,081.54 2.89 -1,753.53 MWD(6) 12,221.97 89.94 319.81 5,869.13 5,813.93 -3,850.42 -232.13 5,990,074.24 476,061.14 8.10 -1,724.18 MWD (6) 12,250.08 90.28 319.80 5,869.07 5,813,87 -3,828.95 -250.27 5,990,095.76 476,043.07 121 -1,697.73 MWD (6) 12,280.84 90.64 320.45 5,868.83 5,81363 -3,805.34 -269.99 5,990,119.43 476,02342 2.42 -1,668.85 MWD (6) 12,311.00 89.29 321.74 5,868.84 5,813.64 3,781.87 -288.93 5,990,142.96 476,004.56 6.19 -1,640.71 MWD (6) 12,341.86 90.15 321.58 5,868.99 5,813.79 -3,757.67 -308.08 5,990,167.22 475,985.49 2.83 -1,612.03 MWD (6) 12,371.98 90.95 322.58 5,868.71 5,813.51 -3,733.91 326.59 5,990,191,03 475,967.06 4.25 -1,584.12 MM (6) 12,400.36 91.35 325.05 5,868.14 5,812.94 .3,711.01 -343.34 5,990,213.98 475,950.39 8.81 -1,558.17 MWD (6) 12,430.42 92.21 326.78 5,86720 5,812.00 -3,686.13 -360.18 5,990,238.92 475,93363 6.42 -1,531.14 MWD(6) 12,461.02 87.70 322.90 5,867.23 5,812.03 -3,661.12 -377.79 5,990,263.98 475,916.10 19.44 -1,503.39 MWD (6) 12,491.92 88.31 320.45 5,868.30 5,813.10 3,636.90 396.94 5,990,28826 475,897.03 8.17 -1,474.69 MWD (6) 12,524.28 90.80 319.36 5,858.55 5,813.35 3,612.15 417.78 5,990,313.07 475,876.27 8.40 -1,444.27 MWD (6) 12,558.72 89.08 318.07 5,868.59 5,813.39 .3,58627 440.50 5,990,339.02 475,853.63 6.24 -141165 MWD (6) 12,586.08 89.91 318.28 5,868.83 5,813.63 3,565.88 458.74 5,990,359.46 475,835.45 3.13 -1,385.66 MWD(6) 12,61460 90.95 316.92 5,868.62 5,813.42 -3,544.82 477.97 5,990,38058 475,816.29 6.00 -1,358.47 MWD (6) - 12,645.92 89.45 312.54 5,868.51 5,813.31 -3,522.79 50022 5,990,402.69 475,794.12 14.78 -1,328.19 MW (6) 12,676.56 90.28 312.47 5,868.58 5,613.38 -3,502.09 -522.81 5,990,42346 475,771.60 2.72 -1,29828 MWD (6) ? 12,705.38 89.51 309.90 5,868.63 5,813.43 -3,483.11 -544.49 5,990,44250 475,749.97 9.31 .1,270.01 MWD (6) 12,735.59 90.61 309.01 5,868.60 5,813.40 -3,463.91 567.82 5,990,461.77 475,726.71 4.68 -1,240.21 MWD (6) 12,765.30 89.97 306.46 5,868.45 5,813.25 -3,44573 591.31 5,990,480.02 475,703.28 8.85 -1,210.77 MW (6) 1 12,795.94 91.08 306.49 5,MB.17 5,812.97 -3,42752 515.95 5,990,498.31 475,678.70 3.62 -1,180.33 MWD(6) 12,825.24 94.15 306.62 5,866.83 5,811.63 -3,410.09 639.46 5,990,515.82 475,655.25 10.49 -1,151.26 MWD (6) I 12,855.51 95.51 309,35 5,064.28 5,809.08 -3,391.53 663.23 5,990,534.45 475,631.54 10.05 -1,12139 MWD (6) 12,903.00 95.51 309.35 5,859.72 5,804.52 -3,361.55 599.78 5,99),564.54 475,59509 0.00 -1,074.75 PROJECTED ro TO . Y72019 9:44:55AM Page 5 COMPASS 5000.14 Build 850 BA ER W' PRINT DISTRIBUTION LIST F UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3S-08CL1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider&bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WALL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. EOA, PROC, PRB-2010mte 109) �D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99508 2 'ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias .3201 C Street, Suite 505 (Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 v_ ?19008 3043 8 ie sign and return one copy of this transmittal form to: 7coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE February 9, 2019 TODAYS DATE March 11, 2019 Revision Details: Rev. Requested by: --- FIELD( FINALCD/DVD FINAL PRELIM (las, tills, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTSX Ur HKIN # OF COPIES # OF COPIES # OF COPIES 9 4 4 4 4 J; 0 0 0 0 0 0 RECEIVED MAR 12 2019 5 DNR- Division of Oil & Gas *** 0 0 1 0 Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential" on all material deliver to DNR 61BP Exploration (Alaska) Inc. Petrotechnical Data Center, 1R2-1 900 F_ Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BAER PRINT DISTRIBUTION LIST F�1 ' UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3S-08CL1PB1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska 219008 30 43 9 ie sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE February 6, 2019 AUTHORIZED BY Patrick Rider EMAIL Patrick RiderCa�bakerhuohes.com TODAYS DATE March 11, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: - COMPANY ADDRESS (FEDEX PALL WT DELVER TO P.O. BOX) PERSON ATTENTION V 1 IBP North Slope. EOA, PBOC. PRB-20 (Office 109) O&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 EsscmMubkl,Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4l State of Alaska -AOGCC Attn: Natural Resources Technician fl 333 W. 7th Ave, Suite 100 'Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 RP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson BKd. Anchorage, Alaska 99508 FIELD I FINAL CD/DVD FINAL PRELIM I (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS9 ur rKIN At OF COPIES # OF COPIES # OF COPIES KI 0 01 0 10 0 RECEIVED 0 0 1 0 0 0 1 0 1 0 0 1 0 TOTALS FOR THIS PAGE: 13- Guhl, Meredith D (DOA) From: Knock, Grace E <Grace.Knock@conocophillips.com> Sent: Monday, March 18, 2019 11:29 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) Cc: Herring, Keith E; Guhl, Meredith D (DOA) Subject: RE: [EXTERNAL]KRU 3S-08CL1, PTD 219-009, Production Test Rates- 24 hours Hello, Please revise the test period rates to the ones below, no changes were made to the calculated 24 hr rates. Date First Production I Method of Operation I Date of Test I Hours Tested I Oil Production for Test Period iGas Producti 2/14/2019 Gas Lift 1 2/17120191 2.61 177.3 I apologize for any inconvenience, let me know if there are any questions, See r^Q'e- 3 Grace Knock AA &r Associate Engineer CTD Development ConocoPhillips Alaska, Inc. Phone: 907-265-6945 From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Sent: Monday, March 18, 2019 9:52 AM To: Knock, Grace E <Grace.Knock@conocophillips.com> Cc: Herring, Keith E <Keith.E.Herring@conocophillips.com>; Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Subject: FW: [EXTERNAL]KRU 3S-08CL1, PTD 219-009, Production Test Rates- 24 hours Grace, Please see Meredith's comment regarding the Production data for 3S-08CL1 at the bottom of the page. Before I respond to her again can you verify your numbers for me. Thanks, From: Guhl, Meredith D (DOA) <meredith.guhl(cDalaska.gov> Sent: Monday, March 18, 2019 8:13 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-SherrodPcontractor.conocophillips.com> Subject: RE: [EXTERNAL]KRU 3S-08CL1, PTD 219-009, Production Test Rates- 24 hours Ann, Still waiting on an answer for this. Thanks, Meredith From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann Haggerty -She rrod@contractor.conocoPhil lios.com> Sent: Tuesday, March 12, 2019 4:02 PM To: Guhl, Meredith D (DOA) <meredith.Ruhl@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-08CL1, PTD 219-009, Production Test Rates- 24 hours Meredith, I will have the production engineer check tomorrow. I already checked and made sure that I typed what she sent me. Ann From: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Sent: Tuesday, March 12, 2019 2:01 PM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod contractor.conocouhillips.com> Cc: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Subject: [EXTERNAL]KRU 3S-08CL1, PTD 219-009, Production Test Rates- 24 hours Hi Ann, Could you please check on the rates reported in the production test for KRU 3S-08CL1? The 24 hour rates seem pretty off compared to what the 2.6 hour rates were recorded as, especially the total MCF for gas. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 me red ith.guh I @a laska.gov Direct: (907) 793-1235 CONFIDENTIALITYNOT/CE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.euhl(aalaska.eov. I Date First Production IMethod of Operation IDate of Test I Hours Tested (Oil Production for Test Period IGas Production for Test Period Iwater Production for Test Period (Choke Size IGOR GOR I Flowing Tubing Pressure I casing Pressure I Oil Calculated 24 hr Rate I Gas Calculated 24 hr Rate FWater Calculated 24 hr Rate Oil Gravity 4031 1981 11651 16371 6601 4921 25.5 k - ..ira Wa�F fir.. 4 V L.- 6av STATE OF ALASKA MAR, 1 1 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANu-LO` a 1a. Well Status: Oil ❑� Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAc 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development 21 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 2/1012019 14. Permit to Drill Number/ Sundry: 21 M08 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 214/2019 15. API Number: 50-103-20450-60.00 4a. Location of Well (Governmental Section): Surface: 2492' FNL, 954' FEL, Sec 18, T12N, R8E, UM • Top of Productive Interval: 1505' FNL, 5141' FEL, Sec 20, T12N, R8E, UM Total Depth: 445' FNL, 1538' FEL, Sec 19, T12N, R8E, UM 8. Date TO Reached: 218/2019 16. Well Name and Number: ' KRU 3S-08CL113S-08CL1PB7 9. Ref Elevations: KB:55 GL: 28 BF: 17. Field / Pool(s): Kuparuk River Oil Field/Kurparuk River Oil Pool ' 10. Plug Back Depth MD/TVD: • 1291815874 ' 18. Property Designation: ADL 380107 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 476305 - y- 5993923 - Zone- 4 TPI: x- 477401 y- 5989627 Zone- 4 Total Depth: x- 475723 y- 5990692 Zone- 4 11. Total Depth MD/rVD: . 1295815876 ' 19. DNR Approval Number: LONS 01.013 12. SSSV Depth MD1 VD: N/A 20. Thickness of Permafrost MD/TVD: , 169611555 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: . 10702/5861 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MHOLE SIZE CEMENTING RECORD D SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H40 33 108 33 108 42 75 sx Arctic Crete 9.625 40 L-80 29 4263 29 2661 12.25 664 sx AS Lite, 391 sx Lite Crete 7 26 L-80 26 8795 26 5847 8.5 181 sx Class G w/GasBlok 2.375 4.6 L-80 10689 12918 5861 5874 3 Slotted/Blank 24. Open to production or injection? Yes [2] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: aIq Aq 10690-11700 MD and 5861.5866 TVD COMPLETION 11821-12918 MD and 58655874 TVD DA't .41ZL1_1 Z4 VERIFIED hf-F✓'✓ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 112 8237 8188/5742 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 2/1 412 01 9 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 2117/2019 Hours Tested: 12.6hrs Production for Test Period Oil -Bbl: vr4 S AW 1 Gas -MCF: I1 S 246 Water -Bbl: µG 53.6'3 Choke Size: 100% Gas -Oil Ratio: 403 Flow Tubing Press. 198 Casino Press: 1166 Calculated 24 -Hour Rate Oil -Bbl: 16 1 Gas -MCF: 660 Water -Bbl: 1 492 Oil Gravitv - API (torr): 26.5 Form 10-407 Revised 512017 V771- 31,;161 C NTINUED ON PAGE 2 Submit ORIGINAL onl� 3/(%(7 RBDMS MAR 12 2019 .-P6 116 � 28. CORE DATA Conventional Corals): Yes ❑ No ❑Q • Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/ro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1696 1555 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10702 5861 information, including reports, per 20 AAC 25.071. Formation @ TPI - Kuparuk C 3S-08CL1PB1 12903 5861 TD 12958 5876 Formation at total depth: Miluveach 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaicalr r well test results. per 20 AAC 26.07 , 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Kai Starck Contact Name: Keith Herrin Authorized Title: eCTD Director Contact Email: Keith.E.Herrin co .com Authorized _ Contact Phone: 263-4321 Signature: Date: I , /'C I STRUCTIO S General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 5/2017 Submit ORIGINAL Only 3S4)8C Final CTD Schematic MW Camc i D8 Nipple Q 502' RKB (2.8]5' ID) 3 ln' 9.30 L40 EUE BN Tubing from surface b 823T RKB 3 -In' Co. KBMG gas IS mandrels Q 4509', 5]]4', 6646', 7367, 8 8138' RKB 3AX Comm DS Nipple Q 8186' RKB (2.812' ID) 4-12' 12.60 LAD EUE 8N Tubmg from BIBS w 12055' RKB 5' loubr sub Q 8196' RKB Baker 5' x T nP liner lop peckerQ 8188' RKB Baker 5-x T' Flax -Lock Hoer hanger Q 8211' RKB Baker 8040 SBE Q 8221' RKB KO Bushing Q 8241' RKB 3S,MMII CTD Completion HMBbudon Suel Packer at I1,]BT MD (min ID 1.5851 - Base pipe 2.063',3.25 Reft. HyddlSl I connection 1.781' RKPmfile M 11,732' MD - "a is 1.647 KOP 10 ]D2' MD 112' 12.60 LA0 shoe Pert Pu vW".6-W'hoks 12,055'RKB 35ABCL1 PBi MTD=12.ieretl Billet -12,028' MD MO 8]05' 87 M LAD shoe Q S' MD Operations Summary (with Timelog Depths) 35-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End TIM our (hr) Phase Op Code Activlty Code TIM P -T -X Operation (ft)(8) End Depth(ftKB) 1/31/2019 1/31/2019 3.00 MIRU MOVE MOB P Continue RDMO from l B 0.0 0.0 16:00 19:00 1/31/2019 2/1/2019 5.00 MIRU MOVE MOB P Hold PJSM with rig / NES team. Start 0.0 0.0 19:00 00:00 loading shop. Pull off well. Install Jeeps. Rig down cellar area 2/1/2019 2/1/2019 12.00 MIRU MOVE MOB P Leave 1 B pad enroute to 3S. 19.7 mile 0.0 0.0 00:00 12:00 move 2/1/2019 2/1/2019 6.00 MIRU MOVE MOB P Arrive at 3S, lots of flowback activity 0.0 0.0 12:00 18:00 on pad. Relocate equipment on pad. Remove jeeps and spot rig on well. 2/1/2019 2/1/2019 5.00 MIRU WHDBOP RURD P Work rig up checklist. Safe out rig, 0.0 0.0 18:00 23:00 R/U putz, Nipple up stack, Rig up MP Line, Change out riser. Get RKB's 2/1/2019 2/2/2019 1.00 MIRU WHDBOP NUND P . Rig Accept 23:00, Fluid pack stack, 0.0 0.0 23:00 00:00 PJSM for BOPE test 2/2/2019 2/2/2019 0.50 MIRU WHDBOP RURD P Stack fluid packed, Start shell test. 0.0 0.0 00:00 00:30 Low held good test, Come up to high pressure 2/2/2019 2/2/2019 2.00 MIRU WHDBOP BOPE T BOP high pressure shell test failed. 0.0 0.0 00:30 02:30 Leaking door seal on ODS lower shear seal. Bleed off, drain stack. Remove door and replace seal 2/2/2019 2/211019 0.50 MIRU WHDBOP BOPE P Reflood stack for shell test. Shell test 0.0 0.0 02:30 03:00 good 2/2/2019 2/2/2019 7.00 MIRU WHDBOP BOPE P Test one good, Test two Lower shear 0.0 0.0 03:00 10:00 seals not sealing. Bleed off and retest. No good. Continue with test 2/2/2019 2/2/2019 0.50 MIRU WHDBOP BOPE P Retest Lower Blind Shear Rams (good 0.0 0.0 10:00 10:30 test), BOP test complete 2/2/2019 2/2/2019 0.30 MIRU WHDBOP PRTS P Slide cart forward, install nozzle, stab 0.0 0.0 10:30 10:48 onto stump, fluid pack surface lines. 2/2/2019 2/2/2019 0.50 MIRU WHDBOP PRTS P Test and chart Inner reel iron and pac- 0.0 0.0 10:48 11:18 off. 2/2/2019 2/2/2019 1.00 MIRU WHDBOP PRTS P PU PDL slab onto stump, line up to 0.0 0.0 11:18 12:18 tiger tank line, P/T and chart test. 2/2/2019 2/2/2019 0.90 MIRU WHDBOP PRTS P Slide cart forward, swap out Upper 0.0 0.0 12:18 13:12 Quick, 67.2 megphm, and >2000 (good -test), P/r Upper Quick, 4,500 psi (good -test) 2/2/2019 2/2/2019 1.75 PROD1 RPEQPT PULD P PJSM, PU/MU Gen II Delta Whipstock 0.0 0.0 13:12 14:57 1 14 1/2",12.60#, OD 2.625" (BOT) 2/2/2019 2/2/2019 0.30 PROD1 RPEQPT PULD P PU/MU CoilTrak tools, function open 0.0 0.0 14:57 15:15 SSV, unable to open, call DSO to assist in cellar. 2/2/2019 2/2/2019 0.75 PROD1 RPEQPT PULD T Function open SSV, unable to function 0.0 75.0 15:15 16:00 SSV open fully, replace stainless plumbing ,function open SSV 2/2/2019 2/2/2019 1.20 PROD1 RPEQPT PULD P Continue PD WS setting assembly 75.0 75.0 16:00 17:12 2/2/2019 2/2/2019 1.90 PROD1 RPEQPT TRIP P RIH, w/WS setting assemby, 75.0 8,295.0 17:12 19:06 1 1 IA=1,300, OA=421 2/2/2019 2/2/2019 0.20 PROD1 RPEQPT DLOG P Log the K1 marker correction of +6', 8,295.0 8,337.0 19:06 19:18 PUW=40K 2/2/2019 2/2/2019 0.60 PROD1 RPEQPT TRIP P Continue in with wipstock 8,337.0 10,815.0 19:18 19:54 2/2/2019 2/22019 0.40 PROD1 RPEQPT TRIP P Clean trip to 10815, PUH for CCL 10,815.0 8,139.0 19:54 20:18 pass 2/212019 2/2/2019 2.90 PROD1 RPEQPT DLOG P 8139', Log CCL to 10815 8,139.0 10,815.0 20:18 23:12 2/22019 2/2/2019 0.40 PROD1 RPEQPT TRIP P Some depth abnormalities during CCL 10,815.0 8,300.0 23:12 23:36 log. PUH to tie into Kt Page 1/9 Report Printed: 2/20/2019 - Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depm StartTime End Time Dff (hr) Phase Op Corte AcOviry Code Time P -T -X Operetion (RKB) End Depth (WS) 2/2/2019 2/2/2019 0.30 PRODt RPEQPT DLOG P Log K1 for+11', Check counter wheel 8,300.0 8,333.1 23:36 23:54 assembly - Good. 2/2/2019 2/3/2019 0.10 PROD1 RPEQPT TRIP P PUH to relog Kt 8,333.1 8,290.0 23:54 00:00 2/3/2019 2/312019 0.10 PRODi RPEQPT DLOG P Log Kt for no correcion 8,290.0 8,329.0 00:00 00:06 2/3/2019 2/3/2019 0.80 PROD1 RPEQPT TRIP P Trip in hole, Slow down to looging 8,329.0 10,725.0 00:06 00:54 speed 9640 - 9677. geo calls on depth, continue in 2/3/2019 2/3/2019 0.10 PROD1 RPEQPT DLOG P Log CCL to see pert Pup, Pert pup @ 10,725.0 10,805.0 00:54 01:00 10,715 2/3/2019 2/3/2019 0.30 PROD1 RPEQPT TRIP P PUH to 10625'. RBIH to set depth @ 10,805.0 10,713.0 01:00 01:18 10712.98', Orient to 180°ROHS. Close EDC. Bring on pumps. See tool shift @ 3800 PSI. Shut down pumps. Set 2.9K down on tray. 2/3/2019 213/2019 0.40 PROD1 RPEQPT TRIP P PUH to 10679', Open EDC. Bleed 10,713.0 10,679.0 01:18 01:42 down WHIP 213/2019 2/3/2019 0.70 PROD1 RPEQPT CIRC P Pump 40 BBLs water / Displace well 10,679.0 10,679.0 01:42 02:24 1 1 to used PwrPro for window milling 2/312019 2/3/2019 1.50 PROD1 RPEQPT TRIP P Trip out of hole, PUW=40K, 10,679.0 8,200.0 02:24 0354 2/3/2019 2/3/2019 0.30 PROD1 RPEQPT TRIP P Communication with tool impeded. 8,200.0 58.0 03:54 04:12 Continue out of well 2/312019 2/312019 1.75 PRODt RPEQPT PULD P Tag up and space out, PJSM, PUD 58.0 0.0 04:12 05:57 BHA#1 2/3/2019 2/3/2019 0.50 PRODi RPEQPT PULD P PJSM, preform valve checklist 0.0 0.0 05:57 06:27 2/3/2019 2/3/2019 0.50 PRODt RPEQPT PULD P Flush & LD setting assembly 0.0 0.0 06:27 06:57 2/3/2019 2/3/2019 1.00 PROD1 WHPST SVRG P Continue Troubleshooting a -line 0.0 0.0 06:57 07:57 issues. Perform INJH inspection maintenance. 2/3/2019 2/312019 3.00 PROD! WHPST RGRP T Repair bulkhead electrical connection, 0.0 0.0 07:57 10:57 test aline, 671>550, PT eline service break 4,000 psi 2/3/2019 2/3/2019 1.50 PROD? WHPST PULD P PD, milling assembly 0.0 63.7 10:57 12:27 213/2019 2/312019 1.70 PROD1 WHPST TRIP P RIH, w/BHA#2 window milling 63.7 8,290.0 12:27 14:09 assembly 2/3/2019 2/3/2019 0.20 PROD1 WHPST DLOG P Log the K! marker correction minus 8,290.0 8,321.0 14:09 14:21 8.5' 2/3/2019 213/2019 0.45 PROD! WHPST TRIP P Continue IH, close EDC, PUW 41 k, 8,290.0 10,702.6 14:21 14:48 dry lag TOWS @ 10,700.5' 2/3/2019 2/3/2019 0.70 PROD1 WHPST TRIP P PUH, perform static pressure survey 10,702.6 10,702.6 14:48 1530 @ 10,693.25' CTMD, Sensor Depth 5,861.48' (TVD) 55 - ECD=11.31 ppg, AP=3,444, 00 - ECD=11.297 ppg, AP=3440 05 - ECD=11.294 ppg, AP=3439 10 - ECD=11.29, ppg, AP=3438 15 - ECD 11.287 ppg, AP=3437 20 - ECD 11.284 ppg, AP=3436 25 - ECD 11.280 ppg, AP=3,435 2/3/2019 2/3/2019 8.30 PROD? WPST PUH, obtain milling parameters, 1.9 10,702.6 10,708.0 15:30 23:48 JHPST bpm at 3,901 psi, Diff -321, WHP=19, IP I IA=622, OA=482. Mill window per procedure 2/3/2019 2/4/2019 0.20 PROD1 WHPST WPST P 10708.0 Call BOW. Continue time 10,708.0 10,709.0 23:48 00:00 1 1 milling to get string reamer out Page 219 Report Printed: 2/20/2019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code ActivityCode Time P -T -X Oparedon (WEI)De End Depth INKS) 24/2019 2/4/2019 1.90 PROD? WHPST WPST P Continue time milling to get strig 10,709.0 10,720.0 00:00 01:54 reamer out. 1.9 BPM @ 3900 PSI, BHP=3487 2/4/2019 2/4/2019 1.10 PROD1 WHPST WPST P TD Rathole. Geo reports formation in 10,720.0 10,680.0 01:54 03:00 sample. Perform 3 reaming passes. Motor work in first pass cleared up by third. 2/4/2019 2/4/2019 0.30 PROD1 WHPST WPST P Perform dry drift, Looks good. Tag TD 10,680.0 10,680.0 03:00 03:18 1 1 1 - Good. ream up on way out. 2/4/2019 2/4/2019 1.70 PRODi WHPST TRIP P Window complete, Open EDC and trip 10,680.0 63.7 03:18 05:00 out 2/412019 2/472019 1.30 PRODt WHPST PULD P At surface, PUD milling assembly, 63.7 0.0 05:00 0618 mills gauged 2.79 no-go 2/4/2019 2/4/2019 1.50 PROD1 DRILL PULD P PD, Lateral drilling assembly 0.0 78.3 06:18 07:48 2/4/2019 2/4/2019 1.75 PROD1 DRILL TRIP P RIH, w/lateral drilling assembly BHA 78.3 8,270.0 07:48 09:33 #3, performing agitator surface test @ 443' 2/4/2019 2/412019 0.30 PROD1 DRILL DLOG P Log the Kt marker correction of minus 8,270.0 8,337.6 09:33 09:51 10.5' 2/412019 2/4/2019 0.60 PROD1 DRILL TRIP P Continue IH, PUW 39 k 8,337.6 10,720.0 09:51 10:27 2/4/2019 2/4/2019 0.20 PROD1 DRILL DRLG P Tag bottom, PUH PUW 38 k, bring 10,720.0 10,724.0 10:27 10:39 pump up 1.88 bpm at 5,241 psi, Diff=1,784 psi, WHP=193, BHP=3,480, IA=676, OA=613 2/4/2019 2/4/2019 0.40 PROD1 DRILL DRLG P PUW 39 k, restart 1.86 bpm at 4,530 10,724.0 10,775.0 10:39 11:03 psi, Diff -1,045, WHP=189, BHP -3,480, IA=692, OA=693 2/4/2019 2/4/2019 4.75 PRODi DRILL DRLG P Stall motor, PUW 42 k, OBD 1.5 bpm 10,775.0 10,853.0 11:03 15:48 at 3,970 psi, Diff --1,350, WHP=187, BHP=3,495, IA=693, OA=694 Note: New mud at the bit 10,777' 2/4/2019 214/2019 2.35 PROD1 DRILL DRLG P OBD, 1.78 bpm at 4,745 psi, 10,853.0 10,928.0 15:48 18:09 Diff --1,580, WHP=175, BHP=3,497, IA=693, OA=695 2/4/2019 2/4/2019 0.15 PROD1 DRILL WPRT P Geo wiper up hole, PUW 38 k 10,928.0 10,860.0 18:09 18:18 2/4/2019 2/4/2019 0.10 PROD1 DRILL WPRT P RBIH to drill ahead 10,860.0 10,928.0 18:18 18:24 2/4(2019 2/4/2019 0.30 PROD1 DRILL DRLG P BOBD, 1.82 bpm at 4,775 psi, 10,928.0 10,952.0 18:24 18:42 Diff --1,555 psi, WHP=168, BHP=3,505, IA=704, OA=724 2/4/2019 214/2019 1.50 PROD? DRILL DRLG P Stall Motor, PUW 49 k, BOBD, 1.78 10,952.0 10,992.0 18:42 20:12 bpm at 4,745 psi, Diff -1,580, WHP=175, BHP=3,497, IA=693, OA=695 2/4/2019 2/4/2019 0.80 PROD1 DRILL DRLG P Stall Motor, PUW 49 k, 1.8 bpm at 10,992.0 11,012.0 20:12 21:00 4,956 psi, Diff -1,580 psi, WHP=138, BHP=3,500, IA=709, OA=733 2/4/2019 2/4/2019 1.50 PROD? DRILL DRLG P PUH, lower pump rate ( attempt to 11,012.0 11,051.0 21:00 22:30 drop in section) 1,5bpm at 3,880 psi, Diff=1,250 psi, WHP=224, BHP=3,504, IA=709, OA=733 2/4/2019 2/4/2019 0.60 PROD1 DRILL WPRT P Plugged off returns, PUH, PUW 41 k, 11,051.0 11,000.0 22:30 23:06 line up to choke A, still plugged off, by- pass MM, able to gel returns, line up to clean MM. 2/4/2019 2/4/2019 0.20 PROD1 DRILL WPRT P Blowdown of choke/micromotion 11,000.0 10,550.0 23:06 23:18 1 ineffective. Pull up into cased hole 2/4/2019 2/5/2019 0.701 PROD1 DRILL WPRT P Work on micro motion, Pull out and 10,550.0 10,550.0 23:18 00:00 snake it. Full of metal shavings Page 3/9 Report Printed: 2/20/2019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Dw(hr) Phase Op code Activity Code Time P -T -X Operation (NCB) End Depth(XKB) 2/5/2019 2/5/2019 0.40 PROD1 DRILL WPRT P Pull up hole to log K1 10,550.0 8,300.0 00:00 00:24 2/5/2019 2/5/2019 0.20 PROD1 DRILL DLOG P Log K1 for +5.5' 8,300.0 8,330.5 00:24 00:36 2/5/2019 2/5/2019 0.50 PRODi DRILL WPRT P RBIH to tie in RA marker 8,330.5 10,720.0 00:36 01:06 215/2019 2/5/2019 0.10 PROD1 DRILL DLOG P Log RA@ 10709, TOWS=10702, 10,720.0 10,740.0 01:06 01:12 1 1 TOW 10704', BOW=10708 2/5/2019 2/5/2019 0.30 PROW DRILL WPRT P Continue in hole, Setdown @ 10,850. 10,740.0 11,055.0 01:12 01:30 Pick up and go right in 2/5/2019 2/5/2019 1.20 PROD1 DRILL DRLG P 11055', Drill, 1.8 BPM @ 4854 PSI FS, 11,055.0 11,140.0 01:30 02:42 BHP=3539, returns=1.74 BPM, RIW=10.1K, DHWOB=3K 2/5/2019 2/5/2019 0.10 PROD1 DRILL WPRT P 11140', BHA wiper, PUW=41K 11,140.0 11,140.0 02:42 02:48 2/5/2019 2/5/2019 0.50 PROD? DRILL DRLG P 11140', Drill 1.8 BPM @ 4776 PSI FS, 11,140.0 11,193.0 02:48 03:18 BHP=3512, RIW=10.8K, DHWOB=.5K. Hard to keep WOB at reduced ROP. 300LBS WOB @ 160 Ft/Hr 2/5/2019 2/512019 2.40 PROD1 DRILL DRLG P PIU lower Flow rate to 1.65 for 100 11,193.0 11,460.0 03:18 05:42 FVHr speed limit, 1.65 BPM @ 4192 PSI FS, BHP=3512, DHWOB 100 to 350LBS @ 115 FPH 2/5/2019 2/5/2019 0.70 PROD1 DRILL WPRT P 11,460', Wiper to window@1.9 BPM, 11,460.0 11,460.0 05:42 06:24 PUW=43K 2/5/2019 2/5/2019 1.60 PROM DRILL DRLG P 11460', Drill, 1.67 BPM @ 4200 PSI 11,460.0 11,629.0 06:24 08:00 FS, BHP=3530, ROP=100 FPH, DHWOB=100 to 400 Lbs 2/5/2019 2/5/2019 1.20 PRODi DRILL DRLG P 11629', Unable to get build with no 11,629.0 11,731.0 08:00 09:12 WOB. Increase ROP to get WOB. DHWOB=400 LBS @ 180 FPH. Reduce rate further to 1.5 BPM to get needed build 2/5/2019 2/5/2019 2.60 PROD1 DRILL DRLG P Increase rale back to 1.8 BPM @ 11,731.0 11,796.0 09:12 11:48 4520 PSI FS, BHP=3565 2/5/2019 215/2019 0.10 PROD1 DRILL WPRT P Pull BHA Wiper, PUW=44K 11,796.0 11,796.0 11:48 11:54 2/5/2019 2/5/2019 2.70 PROD1 DRILL DRLG P 11796', Drill, 1.8 BPM @ 4930 PSI FS, 11,796.0 11,860.0 11:54 14:36 BHP=3565, RIW=10.5K, DHWOB=.2K 2/5/2019 2/5/2019 0.90 PROD? DRILL WPRT P 11860', Wiper to window with tie in for 11,860.0 11,860.0 14:36 15:30 +3' 2/5/2019 2/5/2019 2.50 PROM DRILL DRLG P 11860', Drill, 1.82 BPM @ 4950 PSI 11,860.0 12,017.0 15:30 18:00 FS, BHP=3570, RIW=9.7K, DHWOB=2.7K, ROP= -30 FPH 215/2019 2/5/2019 2.30 PRODt DRILL DRLG P Drilling, 1.8 bpm, CWT= 11 K, WOB 12,017.0 12,260.0 18:00 2018 =AK (reduced WOB to maintain 100 fph), annular= 3599 psi, WHIP = 101 psi, circ = 4948 psi 2/5/2019 2/5/2019 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW=43K 12,260.0 11,410.0 20:18 2036 2/5/2019 2/5/2019 0.40 PROM DRILL WPRT P Wiper in-hole, RM = 11.3K 11,410.0 12,260.0 20:36 21:00 2/5/2019 2/6/2019 3.00 PROM DRILL DRLG P Drilling, 1.8 bpm, CWT = 12,7K, WOB 12,260.0 12,443.0 21:00 00:00 =.8K, annular = 3608 psi, WHIP = 64 psi, circ = 5159 psi, pressure swings (possibly agitator, apparently since BHA went in-hole), transducer indicates agitator is working, elevated gamma (up to 172 API), though continued significant gloconite over shakers. Page 419 Report Printed: 212012019 Operations Summary (with Timelog Depths) 3S -O8 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time our (hr) Phase Op code Activity Coria Time P -T -X Operation (MB) End Dept (hKa) 2/6/2019 2/612019 2.00 PROW DRILL DRLG P Drilling, 1.73 bpm, CWT= 8.8K, WOB 12,443.0 12,539.0 00:00 02:00 = 2.81K, annular = 3620 psi, WHIP = 110 psi, circ = 4749 psi, PU's to work through lower ROP intervals (one PUW @ 54K), no issues RIH 2/6/2019 2/6/2019 0.80 PROM DRILL DRLG P Drilling, 1.72 bpm, CWT = 1OK, WOB 12,539.0 12,586.0 02:00 02:48 =.7K, annular = 3669 psi, WHP = 99 psi 2/6/2019 2/612019 1.70 PROD1 DRILL WPRT P Early wiper to allow geo's time to 12,586.0 8,282.0 02:48 04:30 evaluate, PUW = 44K, pump 5x5 sweeps, geo's believe low in section, complete wiper to tubing tail 2/6/2019 2/6/2019 0.20 PROD1 DRILL CLOG P Log Kt for+5' correction 8,282.0 8,335.0 04:30 04:42 2/6/2019 2/6/2019 1.40 PROD1 DRILL WPRT P Wiper in-hole, Set down @ 11116 & 8,335.0 12,590.0 04:42 06:06 11123, Continue in 2/6/2019 2/6/2019 0.80 PROM DRILL DRLG P 12590', Drill, 1.5BPM @ 4170 PSI FS, 12,590.0 12,708.0 06:06 06:54 BHP=3640. drilling low rate high ROP to get build 2/6/2019 2/612019 0.10 PRODt DRILL WPRT P PUH to get survey, PUW=42K 12,708.0 12,708.0 06:54 07:00 2/6/2019 216/2019 2.20 PROD1 DRILL DRLG P 12,708', Drill, 1.52 BPM @ 4265 PSI 12,708.0 12,816.0 07:00 09:12 FS, BHP=3715 2/6/2019 2/612019 0.70 PRODt DRILL DRLG P 12816, Drop WHP 30 PSI from 150 to 12,816.0 12,849.0 09:12 09:54 120 PSI. Increase rate to 1,8 BPM. BHP=3710 2/6/2019 2/6/2019 0.90 PROM DRILL DRLG P 12849, Drop WHP to 90 PSI, 12,849.0 12,877.0 09:54 10:48 BHP=3630, 1.79 BPM @ 5280 PSI FS 2/612019 2/6/2019 0.10 PROD? DRILL WPRT P BHA wiper, PUW=47K 12,877.0 12,877.0 10:48 10:54 216/2019 216/2019 0.50 PROD1 DRILL DRLG P 12877', Drill, 1.8 BPM @ 5195 PSI 12,877.0 12,903.0 10:54 11:24 FS, BHP=3685 21612019 2/6/2019 2.10 PROD1 DRILL WPRT P 12903, Pull early wiper to sort out 12,903.0 10,689.0 11:24 13:30 hole, PUW=46K. Pull into 4 112 and jog /jet 2/6/2019 2/6/2019 0.60 PROD1 DRILL PRTS P Stop and obtain 30 min static, 10,689.0 10,689.0 13:30 14:06 BHP=3378 @ 5861 TVD sensor for 11.09 EMW, PUW=40K, 2/6/2019 2/6/2019 0.70 PROD1 DRILL WPRT P Run back in hole. Log RA for+6' 10,689.0 12,861.0 14:06 14:48 correction. clean trip down to 12861 2/6/2019 2/6/2019 1.30 PROM DRILL WPRT P Continue trying to gel to bottom and 12,861.0 12,861.0 14:48 16:06 drill, Pick ups getting heavy with packing off. Unable to get past 12896' 216/2019 2/612019 1.40 PROM DRILL WPRT T Pump 5 X 5 sweeps go up and jog 4 12,861.0 8,290.0 16:06 17:30 1/2 to tubing tail 2/6/2019 216/2019 1.40 PROM DRILL WPRT T RBIH, pump 5x5 sweeps 8,290.0 12,500.0 17:30 18:54 2/6/2019 2/6/2019 2.80 PROD1 DRILL TRIP T POOH, pulled heavy (61K) @ 11,162', 12,500.0 78.0 18:54 2142 run back though area up & down, clean, open EDC, PJSM **Pre -load PDL w/ BHA #4 216/2019 2/6/2019 1.30 PROD1 STK PULD T PUD BHA#3 (new floor hand), bit 78.0 0.0 21:42 23:00 came out a 5-5 (tracking down model number as not legible on bit) 21612019 2/7/2019 1.00 PROD1 STK PULD T Begin PD BHA #4 Anchored Billet 0.0 0.0 23:00 00:00 1 1 ssembly 217/2019 2/7/2019 0.60 PROD1 K PULD T Complete PD BHA #4 Anchored Billet, 0.0 73.0 00:00 00:36 slide in cart, UT coil (thinnest = .194"), 161 check pack -offs, MU to coil, tag up, set counters, EDC open Page 5/9 ReportPrinted: 212 012 01 9 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Deptn start Time End Time Dur (hr) Phase Op Code Activity Code Tome P -T-% Operatian (MB) Erb Depth (WB) 2/7/2019 217/2019 1.70 FROM STK TRIP T RIH w/ BHA #4, EDC open 73.0 8,300.0 00:36 02:18 2/7/2019 2/7/2019 0.10 FROM STK DLOG T Log K1 for -7.5' correction 8,300.0 8,337.0 02:18 02:24 2/7/2019 2/7/2019 1.20 PROD1 STK TRIP T Close EDC, PUW = 39K, continue 8,337.0 12,041.8 02:24 03:36 RIH, arrive at setting depth, bring up pumps, shear off at 4700 psi, set down 3.7K WOB, TOB = -12,030', oriented 150" ROHS 2/7/2019 2/712019 2.60 PROD1 STK TRIP T POOH, took -15 bbl lower density 12,041.8 61.0 03:36 06:12 mud to tiger tank "PDL pre -loaded 2/7/2019 217/2019 1.30 PROD1 STK PULD T Tag up and space out. PJSM PUD 61.0 0.0 06:12 07:30 BHA #4 Billet setting BHA 2/7/2019 2/7/2019 0.90 PROD1 STK PULD T PD BHA#5 with 1.2° AKO motor to 0.0 78.3 07:30 08:24 kick off billet and drill turn section 2/7/2019 2/7/2019 1.30 PROM STK TRIP T RIH, BHA #5, Test agitator @ 445', 78.3 8,300.0 08:24 09:42 1 1 1 Continue in 2/7/2019 2/7/2019 0.10 PRODi STK DLOG T Log Kt for -7.5', 8,300.0 8,333.0 09:42 09:48 2/7/2019 2/7/2019 1.10 PROD1 STK TRIP T Continue in well. Pull wt check @ 8,333.0 12,028.5 09:48 10:54 10650 38K, Continue in. Dry tag billet @ 12029.5 217/2019 2/7/2019 1.50 FROM STK KOST T 12028.5 start milling, 1.81 BPM @ 12,028.5 12,030.4 10:54 1224 4720 PSI FS, BHP=3670. Time mill 1 FPH 217/2019 2/7/2019 1.20 PROD1 STK KOST T 12030.4. Start pushing, Drill ahead 12,030.4 12,084.0 12:24 13:36 1 11.81 BPM @ 4720 PSI FS, BHP=3590 2/7/2019 2/7/2019 0.20 FROM DRILL WPRT T Wiper trip to 12,000'. Drift billet area - 12,084.0 12,084.0 13:36 13:48 Good 2/7/2019 2/7/2019 0.30 FROM DRILL DRLG T 12084', Drill, 1.56 BPM @ 3945 PSI 12,084.0 12,130.0 13:48 14:06 FS 2/7/2019 2/7/2019 0.10 FROM DRILL WPRT T 12130 Pull DO wiper. PUW=42K 12,130.0 12,130.0 14:06 14:12 2/7/2019 2/712019 0.90 PROD1 DRILL DRLG T 12130', Drill 1.51 BPM @ 3910 PSI 12,130.0 12,205.0 14:12 15:06 FS, BHP=3635 2/7/2019 217/2019 0.10 FROM DRILL WPRT T 12205', BHA Wiper, PUW=41K 12,205.0 12,205.0 15:06 15:12 2/7/2019 217/2019 1.80 FROM DRILL DRLG T 12205', Drill, 1.5 BPM @ 3900 PSI 12,205.0 12,255.0 15:12 17:00 FS, BHP=3625 Found ankorite 2/7/2019 2/7/2019 3.60 FROM DRILL TRIP T 12255, Call end of tum. Trip for lateral 12,255.0 78.0 17:00 20:36 BHA, PUW=42K, jog 4-1/2" 2/7/2019 2/7/2019 0.90 PROD1 DRILL PULD T PJSM, PUD BHA #5, bit came out 5-3 78.0 0.0 20:36 21:30 2/7/2019 2/7/2019 1.20 PROD1 DRILL PULD T PD BHA #6 Lateral Assembly (NOV 0.0 78.0 21:30 22:42 Agitator, 0.5° AKO motor, RB HCC P104 bit), slide in cart, check pack - offs, MU to coil, tag up, set counters Crew change, PJSM 2!712019 2/8/2019 1.30 PROM DRILL TRIP T Begin RIH w/ BHA #6 78.0 5,935.0 22:42 00:00 2/8/2019 2/8/2019 0.50 PROM DRILL TRIP T Continue RIH w/ BHA #6 5,935.0 8,300.0 00:00 00:30 2/8/2019 2/812019 0.10 FROM DRILL DLOG T Log K1 for -8.5' correction 8,300.0 8,344.0 00:30 00:36 2/8/2019 2/8/2019 1.30 FROM DRILL TRIP T Continue RIH, window PUW = 39K, 8,344.0 12,255.0 00:36 01:54 stack 4.5K at 10,863', PUW = 39K, gel by on 3rd attempt (reduced rate & adjust TF 10", bring rate back up once through) Page 619 Report Printed: 2/20/2019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depe, Siert Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operedon (WB) End Depth (MB) 2/8/2019 2/8/2019 2.10 PROD1 DRILL DRLG T Drilling, FS = 1020 psi @ 1.85 bpm, 12,255.0 12,475.0 01:54 04:00 CWT= 11 K, WOB = 0.2K, annular= 3704 psi, WH = 61 psi, circ = 4572 psi, new mud at bit 12,265', control drilling 100 fph **Man -down drill 2/8/2019 2/8/2019 2.10 PROD? DRILL DRLG T Drilling, CWT = 10K, WOB = 0.3K, 12,475.0 12,660.0 04:00 06:06 annular = 3647 psi, WHP = 153 psi, circ = 4327 psi 2/8/2019 2/8/2019 0.30 PROD1 DRILL WPRT T 12660', Wiper to 12,050, PUW=42K 12,660.0 12,660.0 06:06 06:24 2/8/2019 2/8/2019 1.40 PROD1 DRILL DRLG T 12660', Drill 1.82 BPM @ 4352 PSI 12,660.0 12,797.0 06:24 07:48 FS, BHP=3660 218/2019 2/812019 0.10 PROD1 DRILL WPRT T 12797, PUH losing returns, Consult 12,797.0 12,797.0 07:48 07:54 with town. Now we are going 1 for 1 218/2019 2/8/2019 1.20 PROD1 DRILL DRLG T 12797', Drill, 1.6 BPM @ 3810 PSI 12,797.0 12,858.0 07:54 09:06 FS, BHP=3615 2/8/2019 2/8/2019 0.15 PROD1 DRILL WPRT T BHA wiper up hole, PUW 43 k 12,858.0 12,858.0 09:06 09:15 2/8/2019 218/2019 1.50 PROD1 DRILL DRLG T BOBD 1.62 bpm at 3,850 psi, Diff --950 12,858.0 12,903.0 09:15 10:45 psi, WHP=73, BHP=3,650, IA=720, OA=658 2/8/2019 218/2019 0.85 PROD1 DRILL DRLG P BOBD 1.62 bpm at 3,850 psi, Diff=950 12,903.0 12,919.0 10:45 11:36 psi, WHP=73, BHP=3,650, IA=720, OA=658 2/8/2019 2/812019 0.15 PROD1 DRILL WPRT P BHA, wiper up hole, PUW 43 k 12,919.0 12,919.0 11:36 11:45 2/8/2019 2/8/2019 3.75 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,530 psi, 12,919.0 12,958.0 11:45 15:30 Diff=1,050, WHP=78, BHP=3,650, IA=729, OA=656 2/8/2019 2/8/2019 0.30 PROD1 DRILL CIRC P PUH, launch 5x5 sweep, 12,958.0 12,958.0 15:30 15:48 2/8/2019 2/812019 1.50 PROD1 DRILL WPRT P Wiper to the tubing tail, PUW 41, 12,958.0 8,300.0 15:48 17:18 circulate bottoms up 2/812019 2/8/2019 0.80 PROD1 DRILL DLOG P Lag Kt for +5'correction, RBIH to 8,300.0 10,651.0 17:18 1806 window 2/8/2019 2/8/2019 0.60 PRODi DRILL DLOG P Obtain SBHP, shut-in choke, shut 10,651.0 10,651.0 18:06 1842 down pumps SBHP: MD bit= 10651.9'. TVD sensor = 5861.8', annular = 3368 psi, EMW = 11.06 ppg 2/8/2019 2/8/2019 0.80 PROD1 DRILL TRIP P RBIH to TD, pump sweeps, begin 10,651.0 12,958.0 18:42 19:30 stacking weight at -12,900' pushing to bottom, unable to work past 12,948', call official TD 12,958' w/correction. 218/2019 2/8/2019 2.60 PROD1 DRILL WPRT P Wiper to swab valve, partial pack -off 12,958.0 78.0 19:30 22:06 waiting for sweeps to exit bit, clears up 21812019 2/8/2019 1.70 PROD1 DRILL TRIP P RBIH 78.0 8,300.0 22:06 23:48 2/812019 2/9/2019 0.20 PROD1 DRILL DLOG P Log K1 for -3.5' correction 8,300.0 8,337.0 23:48 00:00 219/2019 219/2019 0.30 PRODi DRILL TRIP P RIH to window 8,337.0 10,650.0 00:00 00:18 2/9/2019 219/2019 2.00 PROD1 DRILL WAIT P Wait on KWF to rig (phase 2 10,650.0 10,650.0 00:18 02:18 conditions), KWF arrives 2/9/2019 2/9/2019 2.90 PRODi DRILL OTHR P Off-load fluid, build LRP, RIH to 10,650.01 12,887.0 02:18 05:12 12,900', stack weight at 12,887'. PUH w/ significant motor -work Page 7/9 Report Printed: 212 012 01 9 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tame Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (WB) End Depl (%KB) 2/9/2019 2/9/2019 3.50 PROD1 DRILL DISP P Lay in LRP (from 12,850) & KWF to 12,887.0 78.0 05:12 08:42 surface, beads up to 9,500', continue POOH 2/9/2019 2/9/2019 0.50 PROD1 DRILL PULD P At surface check well for Flow, PJSM 78.0 78.0 08:42 09:12 for laying down tools 2/9/2019 2/912019 0.25 PROD? DRILL PULD P LD drilling BHA on a dead well, 78.0 0.0 09:12 09:27 inspect CT above CTC, ( 4.0' up from free end 0.118") 2/9/2019 2/9/2019 0.40 COMPZ1 CASING PUTB P Prep RF for Liner Ops, PJSM 0.0 0.0 09:27 09:51 2/9/2019 2/9/2019 2.90 COMPZ1 CASING PUTB P PU/MU Liner segment #1 0.0 1,034.0 09:51 12:45 2/9/2019 2/9/2019 0.70 COMPZ1 CASING PULD P PU/MU BHI CoilTrak tools 1,034.0 1,078.1 12:45 13:27 2/9/2019 2/9/2019 1.75 COMPZ1 CASING RUNL P RIH, Liner BHA#7 w/36 jrts of slotted 1,078.1 9,300.0 13:27 15:12 liner, shorty deployment sleeve, and non -ported bullnose. 2/9/2019 2/9/2019 0.20 COMPZ1 CASING RUNL P Log the Kt marker correction of minus 9,300.0 9,340.0 15:12 15:24 9.01, 2/9/2019 2/9/2019 1.00 COMPZ1 CASING RUNL P Continue RIH, PUW 38 k, 9,340.0 12,918.0 15:24 16:24 DHWOB=3.2 k, set down 12,918', PUW 48 k, RBIH, set down 3.0 k, 2/9/2019 2/9/2019 0.50 COMPZ1 CASING RUNL P Bring pump online 1.5 bpm, Diff -1,113 12,918.0 11,866.5 16:24 16:54 psi, PUW 38 k, remove liner length from BHA 2/912019 2/9/2019 2.10 COMPZ1 CASING TRIP P PUH to log the RA marker for no 11,866.5 43.0 16:54 19:00 correction, continue POOH, PJSM, check well for Flow 2/9/2019 2/9/2019 0.70 COMPZ1 CASING PULD P PUD BHA#7 43.0 0.0 19:00 19:42 2/9/2019 2/912019 0.50 COMPZ1 CASING BOPE P Suck out slack, perform function test 0.0 0.0 19:42 20:12 2/92019 2/9/2019 3.00 COMPZ1 CASING PUTB P Clear Floor, PJSM, PU Liner Run #2 0.0 1,200.0 20:12 23:12 (ported BN, slotted, swell packer, nipple, slotted, & shorty) 2/9/2019 2/10/2019 0.80 COMPZi CASING PULD P PU BHA#8 liner running tools 1,200.0 1,240.0 23:12 00:00 2/10/2019 2/10/2019 1.50 COMPZi CASING RUNL P RIH wl BHA #8 Liner Run #8 1,240.0 9,475.0 00:00 01:30 2/10/2019 2/10/2019 0.10 COMPZI CASING DLOG P Log K1 for -9.5' 9,475.0 9,502.0 01:30 01:36 2/10/2019 2/10/2019 1.00 COMPZ1 CASING RUNL P Continue RIH, 0' correction to window 9,502.0 10,689.0 01:36 02:36 flag, PUW = 39K, continue RIH to set depth, PUW = 41 K, release off liner, PUW = 37K, TOL - 10,689' 2/10/2019 2/10/2019 2.50 DEMOB WHDBOP DISP P Displace well to seawater 10,689.0 4,065.0 02:36 05:06 2/10/2019 2/10/2019 2.00 DEMOB WHDBOP FRZP P Freeze protect from 2500' to surface 4,065.0 45.0 05:06 07:06 2110/2019 2/10/2019 1.22 DEMOB WHDBOP PULD P PJSM, PUD/LD setting tools 45.0 0.0 07:06 08:19 Note: FTP 1,000 psi SBHP: MID -bit = 10651.9', TVD sensor= 5861.8', annular= 3368 psi, EMW = 11.06 ppg Page 8/9 Report Printed: 2/20120191 Operations Summary (with Timelog Depths) 3S -O8 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (fiKB) End Depth(flKB) 2/10/2019 2/10/2019 2.18 DEMOB WHDBOP CIRC P Displace coil to Drilling Fluid for testing 0.0 0.0 08:19 10.30 NS release tool, obtain baseline parameters, unstab INJH, MU release tool, obtain parameters, test tool (good -test), unstab INJH, dogs had retracted, tool functioned properly. 2 bpm/30min/4.700 psi/Diff=1,630 psi 2 bpm/5 min/1,250 psi choke/5,400 psi/Diff=1,850 psi 2.25 bpm/5 min/1,250 psi choke/5,350 psi/Diff=1,900 psi 2.5 bpm/5 min/1,250 psi choke/5,520 psi/Diff=2,200 psi 2/10/2019 2/10/2019 0.30 DEMOB WHDBOP DISP P Displace coil to SW @ 2.5 bpm at 0.0 0.0 10:30 10:48 4,443 psi 2/10/2019 2/10/2019 1.00 DEMOB WHDBOP RURD P MU Nozzle, stab INJH, jet stack and 0.0 0.0 10:48 11:48 surface lines, unstab remove nozzle, remove BHI UO Float Valves, install coil clamp, slide cart back and secure for Rig move. 2/10/2019 2/10/2019 4.70 DEMOB WHDBOP RURD P Work on RD checklist, notify DTH 0.0 0.0 11:48 1630 release tiger tank and hard line, remove and clean pits, 2/10/2019 2/10/2019 0.50 DEMOB WHDBOP RURD P Freeze protect well head, Nipple down 0.0 0.0 1630 1700 stack "" Note: Rig Release @ 17:00......... Page 9/9 Report Printed: 2/20/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3S Pad 3S-08CL1PB1 50-103-20450-70 Baker Hughes INTEQ Definitive Survey Report 07 March, 2019 BAT(ER UGHES ConocoPhillips BA,� 0 Conoco Dei Defindive Survey Report Company ConoccPhillips Alaska lnc_Kuparuk Local Coondmate Relerenci Wall 3S-08 Project: Kupamk River Unit TVD Reference: 3S-08C®55.20usR(Di 141) See: Kupamk 3S Pad MD Reference'. 3S -08C 0g 55.20us11loci 141) Well: 3548 North Reference: True Wellbore: 3S -08C Survey Calculation Memdd: Minimum Curvature Design: 35-08CL1 Pel Database: EDT 14 Alaska Production Project Kupamk River Unit Nor0l Slope Alaska. United States Map Systam: US State Plane 1927 (End solution) System Datum: Mean See Level Geo Datum: NAD 1927 (NAOCON CONUS) Using Well Reference Point Map Zone: Mandi Zone 04 Using geodetic scale Rotor Well 35-08 Well Position +W4t 0.00 Usu Northing: 5,993,923.52us11 latilude: 70.23`40.307N +ELW 0.00 USE Ending: 478,305.45usu Longitude: 150° 11'34.034 W Position Uncertainty 000 USX Wallhead Elevation: 27.50usu Orountl Level: 27.70 us0 Attitude 3S08CL1PB1 Magni Model Name Sample Data Discussed. DIPAngta Said Strength, (9 PI Int BGGM2018 4I1I2019 16.55 80.87 57,414 Design 35-08CL1 PS �— ——- _ Audit Notes: Version: 10 Phase: ACTUAL Te on Depth: 10,650.01 Vertical Section: Depth From [TVD) +WS + UW Dlmdbn (vei (daft) (use) (') 27.50 0.00 0.00 300.00 WM19 9:44:554M Page 2 COMPASS So0p 145uld S5D ConoeoPhillipstM Conoc( Phillips Definitive Survey Report Company: ConoccPhitlips Alaska Inc Kupamk Project Kupamk River Unit Site'. Kupamk 3S Pad Well: 35-00 Wellbore: 3S-0BC Design: 3S-0SCLIPBI Local Coordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Database: We135Ae 3S -00C @ 55.20us8 (Doyon 141) 3&08C ® 55.20us1(Doyon 14 1) True Minimum Curvature EDT 14 Alaska Production Survey Program Om From Td Surwy Survey lure) (dealt) Survey rymllboml Tool ft. Description Start Data End gate 85.90 85.90 35-08 CB-GYRO5S (35A8) GS -GYRO -SS Camara based gI. eingk shat 22512003 212512003 194.59 4,207.48 35-0811FR(3S48) MWD+IFR-AK-CAZSO MWD+IFRAKCAZSCC 2252003 3WO03 4,262.50 8,700.39 3&00C IIFR+MS+SAG Halliburton l3&0 MWD+IFR-AK-CAZSO MWD+IFRAKCAZSCC 121142007 1211712007 8,823.57 10,650.01 3&O8C IIFR+MS(3S-0SC) MWDNFR-AK-0AZSC MWD+IFRAKCAZSCC 121142007 1212008 10,702.00 10,340.20 3S-OeCL1PB1 MWD4NC(3648CL1PB1 MW INCONLY MI INC ONLY FILLER 2152019 2152018 10,87596 12,05551 354OCL1P51 MWD(35-O0CL1P01) MWD MWD -Standard MoO19 24612018 Survey Mars Mars NO Mc Ari M Mike +WS +&M Homing Earl D" Section Section Same, Tool Noma Annotation luaf) (1) M (-am lam) (kaR) Iwe) (ft) M1 (.1107) IN) 10,YA.01 90.41 241.87 5,851.55 5,806.35 ,,267.65 1,15447 5908652.05 42744826 4.91 313363 MW0.1NC ONLY (5) TIP 10,]01.[0 91.45 239.41 5060.20 S,e05.50 4,28113 1,109.12 5,M,627.n 477.40090 5.14 4,10214 MW0.1NC ONLY(5) KGP 10,720.24 00.08 20.67 5,88065 5.81 4,30210 1.09329 5899,618.40 477384.99 ISAM 3.097.87 MWO-INC ONLYIS) Inleryokted Azimuth lono06 9395 244.09 5,860]0 5'ats 50 431560 1,088.40 5,549,801.99 47{358.14 1279 .3.001.40 MW4INOONLY(5) Interpolated Azimuth 10,780)8 88.47 24846 MOM 5,1105 to 4,,327.75 1.038.50 5,659.592.93 477.33012 1345 3.053.01 kNA-INC ONLY (S) Interyolated A2imum 10,010.01 09.3D 25137 5,85144 5.&Ms24 ,.33513 1010.33 590950264 47730192 11.04 1044.04 yhVoINC ONLY (5) Interyolated Azimom lonsid 0 09.03 2S4.S2 588171 5,806.51 4,345.75 962,24 5,909.57411 477,273.81 1070 3,024.02 MJVTI-INC ONIY(S) Interpolated Azimuth 10075.88 9035 25535 588175 5005.55 4,355.14 9246 5,909.56583 471.239.03 10.85 -2.008.11 WA)(6) 1g910.a4 90.00 261.47 5..l,. 5005.24 4,361.10 913.54 5,809.55990 27.205.07 9.19 -2,971.74 MND(6) 1D..O21 Sereg 264.05 5,88131 5.808.11 X3..93 884.01 5,989.55524 477175.53 9.43 1,940.. MNO (6) 10.95983 89.82 264.30 5.861.8 5.885.19 ,,356.89 864.89 5,909,554.35 47/.156.21 183 3,932.29 MWO (6) 10997.. 89.72 26589 5.06154 5,806.34 ,,369.73 0278 5,809,55162 477,11890 6.71 -2901.41 MND (6) t1,p2949 BB.t6 2059] 5,882.71 5,807.51 4,371.47 795.. 5,988 549.89 477,86.52 10.97 3.074.24 MND (6) t1W0.60 8].15 269.64 5,664.52 580832 4,371.39 763.97 5,989.549.17 477055.48 9.14 4.84781 ~(6) 1109152 0761 Aro'. 5.fie5. 5,010.74 4,373.32 MAO 5989,548.33 477D2461 8.99 4,821.55 MM (6) 1111980 9104 26au7 5066.27 5,811.07 ,,37155 704.80 5,989,547.18 475.996.32 1281 -2.7971ft MID 1115000 90E4 270.51 5.865.83 5,810.63 ,,374.94 67005 5.989,546.93 4MAnsm 8.19 -2,771.74 MWD (6) WM19 8;44;SSAM Page 3 COMPASS 5000149mid 05D ConocoPhillips ConocoPhiliips Definitive Survey Report Compatry: Cono.Philhps Alaska Inc Kupamk Local C.Mi.Ma Reactor.: Well 3511 PmfecD Kupamk River Unit TVD RefereM.tl 3S-08C®55.20us8(Doyan 141) Site: Kupamk 3S Pad MD Reference: 35-080®5920us8(Doyon 141) Well: 3500 North ReMrence: True Wellbore: 35 -DSC Survey Calculation Method: Minimum Curvature Design: 35-DBCL1 P51 D9Mbaae: EDT 14 Alaska Production Survey Map Map VeRNaI MD Me Aid TVD Mile 460E avv Northing Eluding DLS Section Tool Mae Surveym Atation nno (Mall) P1 19 (tMfg (-am IMaR) (Ma1ry(RI IRI Viler) (R) 11.10.32 90]1 27485 5,86542 5.81027 4,373.52 644.39 5.989,549 .42 4]693591 1435 -274481 mujti1 11,ZI8.64 Lb.89 28.60 Semon 5.809.86 -037033 61525 5999.551.69 476 90&7S 9.35 -2.]1].99 MD (6) 11,239.]0 ad,21 270.35 5,864" 5.808.57 4,30.16 50.48 5,999.555.0 4706]].0 3.37 -2.690.12 AYD(6) 11,269.57 0991 280.31 5,064.74 5,009.54 -0,361.32 556.0 5,9a9560.89 4]6,8425] 8.84 4.02]8 M (6) 1130.43 09]9 28294 5060.03 5009.63 4,354.50 522.64 5,999.58].02 4]6,81444 ].]8 -2.00.04 MD (6) 11,329.51 69.85 2&5.60 5,064.91 5,009]1 4,348.19 49254 590,94.21 4]6]89.16 8.17 -3.604.99 MND(6) 11,%1.98 89.97 280.61 5.864.0 5,009.76 4,338.78 45647 5,9095N.R 4]6,]59.12 11.0 -2.52336 MND(6) 11,389.64 8942 289.32 5,80,11 5,80991 4,323.28 440.31 5,909593.60 4]6]31.99 3.16 -2,516.21 MD (6) 114W 65 9909 293.40 5,89.30 5810.10 4,31849 411.44 59autem 18 4]6)03.16 13.24 -2.51556 MD (6) 11445.12 9900 294.97 5.655.35 5.010.15 -0,30.46 30912 5,889.614.0 476,600.02 6.42 -2.491.M "D (6) 11,475.01 0945 29]1] 5,80.53 5,01033 4295.33 3622] 5,989,622.49 47665402 2.50 -2,481.40 MD (6) 11,50.29 Mew 298.85 5,865.84 5.010.64 4,201.11 335.`A 598,9641,M) 4]682].39 559 -2.431.14 MD (6) 11,54045 80]4 300.86 580.42 5,811m 4.20,61 3050 5,989,659.39 4]6591i,% 595 8395.98 "D (6) 1157042 89R 30201 58063 5,011.63 4.242.00 279.60 5,900,67520 4]6.5]10 ]30 3,3580 MWD(6) 11.600.fi4 89R 302.30 5Mal 5811,77 4,231.54 25413 5,90969162 476,$46.14 1.69 -2,335.85 MWD(6) 11631.0 8902 301.19 5857.10 501190 -0215.0 227.49 5,989)00.10 476,519.58 160 -2,30454 MWD(6) 1101.0 90.15 301.21 5,607.11 581191 4199.97 2E.0 5,989]Y1.64 426.49431 1.11 -22]4.05 MWD(6) 11.692.4 91.63 29042 5.860.63 5011.43 4,184.53 125.67 5,989,]38.8] 4]8.48].84 10.37 -2744.40 laWD(5) 11,MSO 90.12 601.10 5.866.14 581094 415646 147.% 5988.755.02 476.439.79 950 221203 MND(6) 11759.51 90.21 303,10 5895.04 5,010.84 4149.86 117.91 5,989,"3.72 476,410.19 572 -2,1]]04 IJWD(6) 11795.36 91.04 30340 5%50 5,01045 4,13031 8293 5,989 793.47 476.38030 246 -2,141.25 IAAD(6) 11830.73 iman Mato 5,86&40 5810.20 4,11020 58.]] 5,989,013.55 4M,351.18 6.92 4.105.99 MD (6) 11864.48 89.02 307.09 5.%&53 5,81033 4,09022 31.55 5,919,833.63 4MX405 4.72 -20]245 MJN(6) 11,691.91 80.9D 30.33 5,865.84 5.810.64 4.074.02 9.44 598964990 428,30192 224 -2,4518 ~ni) 11.974,46 88.44 30].0] 5,84649 5,811.29 4.057,34 -13.35 5.986% .6.65 229. 4]6,24 6.37 2MN 01].10 D(6) 1195246 68.02 307,66 5.8,248 5,81220 4,03273 19.03 5969.865.33 426Y da 2.15 1..507 MWD (6) 11,900.92 gain 30.90 s'.Cs 5,812.85 4020.12 .61.35 5989904.01 476.231.37 6.92 -1.956.93 MD (6) 12,04&t U.79 311.24 5.06922 5,81302 -3,999.58 -05.A 5,969.924.83 476202.02 2.38 4,925.51 MD (6) 12,640.91 93.55 312.28 580.14 5812.94 J,990.08 -10.21 5,969.943.39 am 10613 4.59 -1,099.02 MD (6) 120]1.03 90.98 315.04 5,862]4 581254 460.. 4200 5986,8.25 41`6164A1 9.27 -1868.76 MD (6) 12 ,1000.1 90.18 31529 5.86244 5.81224 J939.10 449.3] 5909995.30 47614364 203 4¢40.1.9 MWD (6) WM19 9;44;&&104 Page 4 COMPASS 500014 9uM 850 Annotation WM199:M: SSAM Page5 COMPASS 5000.14 S BSD ConmoPhillips COnocoPhilliP5 Definifive Survey Report Map C.pw.. C.nn,.Phillipa Alsska lnc Kuparvk Local Coarainate Reftmnu: )M,11 3S.06 �P.Jacf: Kuparvk River Unit WD Reference'. 3S-OOC®55.20ua3(D.y.n 14 1) SBv. Kuparvk 3S Pad MD Rehmnce'. 35-DBC®55.20us8(Do"n 141) W4i 35-08 North Rehrence: True WMb9n: 35-0BC Survey Calculml.n Meth.@ Minimum Curvature �Denly.: 3S-08CLlPBt Database: EDT 14 Alaska P.d.nti.n Swuy (-am (10 Int Annotation WM199:M: SSAM Page5 COMPASS 5000.14 S BSD Map Map Vertical MD Inc Ail 1V0 1VD83 aWA ♦EFW N O Ea OLS -now) Section Survey Tool Nanta (aall) PI PI loath (um" Wall (-am (10 Int (ft) WI I (ft) 4.130.91 Bfl]) 316.26 586712 5,81252 -3,91740 -1]0.48 5.930.00].0] 4]6.133.5] 5.65 -1 811 C6 MWD (6) 12,160.94 W. 3W. 5813035 5013.15 -,895.65 -19117 5,903.028.89 476.101.113 191 -0,]0226 MWD (6) 12,190,99 a.14 31]43 505080 5,813.60 -,873.66 -21166 5.990.05093 476,05154 209 -.]53.53 MD (6) 4.22197 Bom 31901 5869.13 5.81593 -3.850.42 -M,13 S.B93p7424 476,03114 8d0 -1.84.18 MD (6) 12,250.08 9020 319.80 5869.07 5,81587 -3,82095 -25027 5,900095]6 4]0,043.0] 1.21 -1,69].]3 MD (6) 4.280.84 90." 32045 5.11MM 5,81363 -3.805,34 -59.99 5,990.11843 476,023.42 242 -1,668.85 MWD(6) 12.311.00 89.5 321.]4 5,866.84 5,81564 -3.]016] -2H.93 5903,142.05 476.DNIM 619 -1,640]1 MD (6) 12.&1W 90.15 321.50 5660.93 5,01379 -3,757,67 .309.00 5,935167,@ aMw,49 2.03 -161203 MD (6) 13.37186 9065 32250 5.868.71 5,813.51 -3,733.91 J W 5.593.19.03 4]5,96]03 425 -1584.12 MD (6) 12,403.5 91.35 3 m 5,868.14 5,81294 -3.711.01 .14334 5,M,213A6 475,8501 8 8.81 -1,550.17 mo (6) 12430.42 9221 3570 5.8675 5,84.00 -3,603.13 dW10 5,886.51192 4]5.83363 642 -1,531.14 MWD(6) 12,46102 87.7(1 32290 5.867.5 5,812.03 -3,W1.12 3]I]9 5,991,53.98 4]5.916,10 19," -1,"539 MWD(6) 12.491.93 80.31 32045 5.038.30 5,813.10 -3.635.90 .1Km 5,99).288.5 475,89103 8,17 -1,47469 MYW (6) 12,U4,M 90.00 319% 5,w..55 5,81335 4t,612.15 -01TTS 5,90,313.07 45816.2] a40 -1"4,2] MW➢(6) 12,558.12 89.08 310,07 5.03959 5,813.39 -,586.27 AQ.." 5,9".339.02 4]5,853.53 624 -1,41165 MOM 12.586,05 86,91 31828 5,809.113 5,813.63 -,565.88 45674 595n,35946 4MAWA5 313 -1.38586 MWID(5) 12.614." 9495 316.92 5.868.62 5.813.42 -a'W.82 4897 5,9",360.56 47581629 6,00 -1,3504 MJU M 4,154592 8945 31254 5.068.51 5.813.31 3.6M79 E00.22 599040269 45,]9412 14.78 1,32619 M (6) 12,676" 90.28 3124 5.858.58 5.81336 3,"2.08 SRB1 5,90,42348 45,1860 272 45620 MD (6) 12705,38 03.51 309." 5858.63 5.813.43 -3,403.11 544.49 5,990442" 45749.97 9.31 42801 MD 12,735.59 90.61 M9.01 5.068.60 5,81340 -,463.91 46782 5,99046177 451571 460 -124021 IMD(6) 12765.30 89,97 305.45 5.¢68.45 5,01325 3,445.73 391.31 599040302 4757.28 885 -1,210.]] MID (6) 12,]95.94 91.08 306.49 5.868.17 5,812.97 3,427.52 E15.95 5,990490,31 475,67670 3.62 -1.180.33 M (6) 1202524 94.15 306.62 5.803.83 5,81163 -341003 .638.46 5,990.515.82 4565525 10.49 -1,1515 mo t6) 12,65551 95.51 309.35 5,864.20 5609.08 -39153 .663.5 5,Sao 534,45 45631.54 10.05 4121.39 MD (6) 12,903.00 9551 309.35 5.M9 5.5. 03 ,All .698]8 5,990 56,`,.4 4]5.595.09 000 -1,07475 PRWECTEDI.TD Annotation WM199:M: SSAM Page5 COMPASS 5000.14 S BSD �, ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3S Pad 3S-08CL1 50-103-20450-60 Baker Hughes INTEQ Definitive Survey Report 07 March, 2019 BAKER JUGHES mmpa ry .: Conocolphillips � • Cono4hdhps oehniDve survey Report Company: ConocoPhillips Alaska lnr_Kupamk Profen. Kupamk River Unit She: Kupamk 3S Pad Well: 35-00 Wellbore: 3S -03C Design: 35-08CL1 Project Kuparuk River Unit North Sbee Alaska, United States Map System: US Stale Plane 1927 (Esau solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Ask" Zone 04 Well 35-08 Local Cu -ordinate Retoucher. NO Reference: MD Reference'. North Reference'. Survey Calculation Memetl: Contacts Well Position 'NIB 0.00 us8 send., Longitude; +FIW 0.00 ush Sinning: Position Uncertainty Oe .tie. 0.00 ush Wellhead Elevation: Wn1Eom 35-OBCL1 (nT) 16.63 Magnaika alotlel Npme hap Sample Data 8GOM2018 2/812019 N4113S-0B 35 -OBC ® 55.20uaX (Doyon 141) 3S48C ® 55.20u0 (Ooyen 141) True Minimum Curvature EDT 14 A3aska Production Mean Sea Level Using Well Referenx Point Using geodetic scale tactor 5,993,923.52ush Lathuda: 70°23'40.307N 476,305.45ush Longitude; 150° 11'34.034 W 27.50ush Ground Level: 27.70 ush Oe .tie. Dip Angle Field Simplifier 19 1°I (nT) 16.63 80,87 57,420 Design 35-08CL1 Audit Notes: Version: 1.0 Phase: ACTUAL The On Depm: 12,012.03 Vertical Section: Depth From(TVD) +WB +EWI Direction (ustt) hap (ue0) 1°I 27.50 0.00 0.00 300.00 3/!2019 9:46:54AM Page 2 ConocoPhillips f Q ConocoPhilli s P Definitive Survey Report Company: ConocoPhillips Alaska lnc Kupamk Local Coordinate Refs...: Well 35-08 PmleCc Kupamk River Unit ND Reference: 35.0901@ 5520usfl(Doyan 141) She: Kupamk 3S Pad MD Reference: 3&08C®55.20ua8(Doyan 141) Well: 3546 North Resonance: Tore Welleon: 3S4 C Survey Calculation Method: Minimum Curvatura Design: 3S -MCI -1 Datne- EDT 14 Alaska Produc0on Survey Program Date Fre. To Survey Survey luabl (paid Survey(Wellb..) Toed Name D ... dp8an S nww End Data 85.80 85.90 35-15 CB -GYRO -55 (35-08) C&GYROSS Camera based gym single shat 212512003 212512003 194.59 4,207.48 M50811FR(354B) MMAFRAK-CAZ-SC MWD+IFRAKCAZSCC 22512003 3820" 4,262.50 8,780.39 3S-0lC IIFR+MS+SAG Halliburlon(35.0 MWDNFR-AK-CAZ-SC MWD+IFRAKCAZSCC 121142009 1217712007 8,823.57 10,85a.U1 M5 BC IIFR+MS(35418C) MWDNFRAK-OAZ-SC MWD+IFRAKCAZSCC 121142007 112112006 10,702.00 10,840.20 354111CL1 PBI MWD-INC(35418CLIPBf MWD -INC ONLY MW41NC_ONLY _FILLER 2152019 2152019 10,875.98 12,012.83 354MCL1PB1 MWi)(3S4111COP81) MWD MWD -Standard 2812019 21 019 12,028.00 12,914.38 3SASCL1(354180Li) MWD MWD -Standard 222019 222019 Saryey Map Map Vertical 90 Irl[ Ail M 1VU8S +5415 +vm Northing Easting OLS Section Survey Teal Name Ann0151i0n teem 11 (1) (U-111 (Ulm luso) (U -M ID) ID) (9100') (0) 12,01283 WIN, 31124 581 581302 41999.58 85.7 5,989,9N63 4]6,207.02 7,36 -1925.51 "D (6) TIP 12'WiLoo 90.20 311.80 5860.23 5813.03 3989.53 97.12 5,809,93412 4]0]9509 4,158 -1,91065 M (7) KOP 12,080.64 82.00 321.11 5 86T 5812.40 -3,565.90 -11950 5,90995&41 476,17331 2.,M -0679.8 MM (7) 12.08540 87." 323.17 5,W7,62 5,812.42 -3.946.35 -134'" 5,909.97&00 4n 156.16 100"1 -1658.48 MD (7) 12.12087 09.11 332.43 5.080.55 5,813.35 8,91655 -153.54 5,990,007.86 47613951 26.40 -0,825]1 him)(7) 1215072 00.7 341." 5,869.11 5813.91 41&98.07 -105.M 5,990,03555 47&127.94 3130 -1,801.38 WD (7) 12,179.09 8917 35070 5,86963 5,814.43 y860M AMID 5,990.0".87 476121.13 3011 -1,78125 MND(7) 1221022 Be. 35542 5,071115 5,81495 J,aoo5w -17574 5.990.094190 478117.50 1532 -tMaki MID (7) 12,24290 &KC2 35264 5,87074 5,815.54 41798." -17914 5,990.12640 47&11439 0.51 -t]43E6 MID (7) 80.59 350.82 5,871.30 SBi6.tfi J,7".fi2 4"41 5,890,155.80 476,110,11 6.30 -1125.47 MWD(7) 112,2173".60 12..83 8&71 348.57 5. n.07 5.01'37 4739.08 4.11]8 5.990.185.43 476.104.84 ]50 -1,706.06 1,1W9(7) 12,332.57 90.05 347.25 5,81739 5,.17.19 417M Ill -195.05 5,980.214.12 476098.65 8.20 -1.0".99 MWDQ) 1234.55 90.25 34555 5.87231 5,017.11 3680.66 -20210 5,990343.00 476,091.71 5.74 -1,636.31 MWD(7) 12,392.54 U. 34351 5.812.16 501606 4,651.77 -21D.08 5.990372.80 476,003.82 6.61 -1,643.95 MWD(7) 12,471.45 8966 340.94 5.87718 5,016.96 4623.26 419.20 5.990,301.31 478.07419 900 -162191 MWD (7) 12.452.54 9021 37.96 5.88.19 581699 -3.59511 -Mom 5,990,32951 415.064.32 10.07 -159&58 MW9 (7) W M19 9'46 MAM Page 3 COMPASS 5000.14 Budd BSD Survey ConocoPhillips C0110C0Philfips Definitive Survey Report Company: ConocDPhillips Alaska Inc_Kuperuk Local Co-Drdlnate Reference: W 113508 Project, Kupamk River Unit TVD Reference: 35-OBC®55.20ush(Dutch 141) Slee: Kupmuk 35 Ped MD Reference: 35-OSC C 55.20ush(Doyon 141) Well: 35.00 North Reference: Tons Wellbore: 35-08C Survey Calculation Method: Minimum Curvature Dehogn: 3"BCL1 Database: EDT 14 Alaska Production Survey Annotation W M19 9:46:54AM Pape 4 COMPASS 5000.14 Sued 850 Map Map Mo Inc Aei TVD TV063 tNIS .0m Northing Ea(114 nL3 Sheehan Semon Survey TODl Name (.ch) (1) (1) Nsh) lush) lush) (Mort) (rt) pt) Moan) R) 12.<81.B9 8994 33532 5,BY2.t5 581695 -3,55825 -241% $.930.356.41 476,052.81 9.07 -1,675.10 MWD(]) 12,51222 Win 331.02 58T1.21 6,,017,01 y541.01 434.60 5,900.3836B 4]6,039.36 11.51 -0$49.76 MD (7) 12,54245 89.08 32]46 56]2.49 5,81729 -5514.94 4)0.1] 5,99].40981 476,024.17 14.65 -1$2349 MWD (7) 12.57184 89.36 324.63 5.8]2.89 5,817,69 -3.49055 486.50 5,9B0AM43 4]6,00].83 9.14 -1,497.09 MWD (]) 12.601.5 Win) 32 03 5.873.11 5817.91 -3.465.97 404.15 5.993,457.88 4]5990.34 8.96 -1,470.00 MWD (]) 12.60.36 90.52 320.3] 5,873.03 5,017,83 -3.444.29 423.38 5,993.400.61 4M,SnAll 6.23 -1,4429$ MWD (]) 12.65982 90.06 31]00 5.8Y1.88 5,817A0 -3.4.iM 441.% 5,990.502.94 4]5952.98 0.53 -1,415.12 MWD (]) 4.60.29 90.71 315.44 5,8n.0 5,81106 -3,38986 -362.57 5,990.52516 4]5932.14 8.02 -1,385.94 "D (7) 12121.15 80.52 31340 5.87193 501573 -3,378.25 404.59 5,990.546.80 475910.19 638 -1,uS6.06 MWD (7) 12749.65 8059 311.57 5.671.65 5,01645 -3,358.98 <050 5,990.5%.18 475,88934 6.70 -t32B.23 MWD(7) 418034 91.51 31016 5,871.08 5,01589 4.338.91 428.80 5990.586.32 4F,ee6.11 550 -0.296.10 MWD (]) 4,81033 90.52 300.67 5,870.1% 5,81536 -3.319.07 451.96 5.90,60543 4]$6u 0l 5.98 -0,260.52 MWD (7) 4.8390 69.29 30160 5,870.61 5.015,41 3Wloa) 47531 590.623.78 4]501983 5.32 -0,239.26 MWD (7) 12.96954 86.84 30]98 5,871.61 5.01e41 ..28361 498.74 5,990.64183 4]5]96.35 6.52 -1.211985 MWD (7) 4,00.98 88.62 30aL% 5873.41 5,018.21 436524 -524.19 5,99066028 47570.98 8.0 1.17866 MAD (7) 1291430 0110 30.0 5674.13 5,01693 4257,00 43531 599066]]5 4n.7%87 1207 -1.16531 MWO(7) 12950.0 87.18 3ML03 5676,20 5,az108 4,234.08 571.84 5,990681.61 415,/23.42 M0n -1.121.80 PROD CTEO b TD Annotation W M19 9:46:54AM Pape 4 COMPASS 5000.14 Sued 850 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-08CL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-008 Surface Location: 2492' FNL, 954' FEL, SEC. 18, TI 2N, R8E, UM Bottomhole Location: 46' FNL, 1894' FEL, SEC. 19, T12N, R8E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.olaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 207-163, API No. 50-103-20450- 03-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 0/7Z--� Daniel T. Seamount, Jr. Commissioner DATED this 18 day of January, 2019. STATE OF ALASKA AL, .<A OIL AND GAS CONSERVATION COMML-iON PERMIT TO DRILL 20 AAC 25.005 RECEIVED AN y 1 a. Type of Work: Drill ❑ Lateral ❑✓ Redrill ❑ Reentry ❑ 111b. Proposed Well Class: Exploratory - Gas LJ Stratigraphic Test ❑ Development -Oil ❑� Exploratory - Oil ❑ Development - Gas ❑ Service- WAG LJ Service - Disp ❑ Service- Winj ❑ Single Zone ❑' Service - Supply ❑ Multiple Zone ❑ 1c. Specify if weJHs proposed for: Coalbed Gas Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Q Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 3S-08CL1 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13525' TVD: 5866' 12. Field/Pool(s): Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 2492' FNL, 954' FEL, Sec 18, T12N, R8E, UM Top of Productive Horizon: 1504' FNL, 141' FWL, Sec 20, T12N, R8E, UM Total Depth: 46' FNL, 1894' FEL, Sec 19, T12N, R8E, UM 7. Property Designation: ADL 380107 8. DNR Approval Number: LONS 01-013 13. Approximate Spud Date: 1/28/2019 9. Acres in Property: 2560 (,.y 14. Distance to Nearest Property: 995' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 476305 y- 5993923 Zone- 4 10. KB Elevation above MSL (ft): 55 6f!' GL / BF Elevation above MSL (ft):! g 15. Distance to Nearest Well Open to Sa a Pool: 2920' (3S-21) 16. Deviated wells: Kickoff depth: 10700 feet Maximum Hole Angle: 91 degrees 17. Maximum Potential Pressures in psig (as 20 5) Downhole: 4447 Surface: 3870 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2835' 10690' 5861' 13525' 5866' Slotted / Blank 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 12055' 5872' N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12055' 5872' WA Casing Length Size Cement Volume MD TVD Conductor/Structural 75' 16" 75 sx Arctic Crete 108' 108' Surface 4234' 9-5/8" 664 sx AS Lite, 391 sx Lite Crete 4263' 2661' Intermediate 8768' 7" 181 sx Class G w/ GasBlok 8795' 5848' Liner 3867' 4-1/2" pre-perfed liner 12055' 5872' Perforation Depth MD (ft): 8750r- 8790' 11 pert pups 9322'- 12001' Perforation Depth TVD (ft): 5843'- 5847' 5843'- 5870' Hydraulic Fracture planned? Yes[-] No R P Sketch 20. Attachments: Property Plat ❑ DiveSO rter Sketch Drilling Program e Sea ed Report v. Depth ot B Drilling FluiProgram E] El Shallow Hazard Analyst's 20 AAC 25.050 requiem B✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. HerringOCOP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: Commission Use Only Permit to Drill Number: �Q�$ API Number: 50- — 0 O Permit Approval Date: I See cover letter for other requirements. r� Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: IJ Other ooP re-st Vv 42 GO S., Samples req'd: Yes [—]NOR'Mud log req'd: Yes E] No ER' 11nnv{a f—p/C vs�7 tr rr,�a�Z 5-0 OvvDb' 5' HzS measures: Yes FR} No❑ Directional svy req'd: Yes[]' No❑ `` Spacing exception req'd: Yes ❑ N,EV Inclination -only svy req'd: Yes E] No Post initial injection MIT req'd: Yes ❑ No a— APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ! O N V __ 11 ZJ II�� /� A Submit Form and ov• N Form 10-401 Revised 5/2017 a his er it is valid foO2 r001tt�slfrd� t at�ptLOproval per 20 AAC 25.00b(g) Attachments in Duplicate R V „L *t $,ot��l9 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 14, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill one lateral out of the KRU 3S -08C (PTD# 207-163) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in late January 2019. The objective will be to drill one lateral KRU 3S- 08CL1 targeting the Kuparuk C -sand interval. Attached to the sundry application are the following documents: - 10-403 Sundry Application for KRU 3S -08C - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Wellbore Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 3S-08CL1 - Detailed Summary of Operations - Directional Plans for 3S-08CL1 - Proposed CTD schematic - Current Wellbore Schematic If you have any questions or require additional information, please contact me at 907-2634321. Sincerely, /, X�, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 3S-08CL1 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))... - .............._.................................... _.......................... _. _.. .................. _.2 2. Location Summary .................. ......... ......... ..... ..... ..... ....... ...... 2 (Requirements of 20 AAC 25.005(c)(2)) ... .... . .... ............. .............. .............. ......... ............ . ...........2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)) .. ........... ....._............. ...... ....... ...... ................ ............ ......_._... ............ _...............2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).. ....._.................................... ....._........... _.......... ..............2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)) ....................... .................. ....._........... . _............ ................ ............... ..................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(5)) .................. ....... ................ ......................... ............... ........... ............... ...................................... 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))............. .......... .... _. _--- ........... . _........ ...................... _........... ........ _.......................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)) ... ..... ................ .................................. .. ........._.. ............. ............. ......_.,..........3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)).. ......__........ ...... .................. .................. _........... .............. ................. ................4 10. Seismic Analysis............................................................................................................................. 4 . (Requirements of 20 AAC 25.005(c)(10)).. ................................... ............. .. ......._. ............................._......................._.4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))............................................................... ......... .............................................. ...... ................... 4 12. Evidence of Bonding .............. ................... .... ..... .... ...... ....... 4 (Requirements of 20 AA C 25005(c)(12)) ..... ....._. .. .. .. ....... .... .......... ... ..... ....._..... ....__.....4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))...... .......................... ........ .._._.,_...... ...._................ .......................... _. .. . .....4 Summaryof Operations............................................................................................... ........ ............ .....4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20AAC 25.005(c)(14)).... .......... ... .. ... .......... .................. _............... ............... ...._............ ..........._...5 . 15. Directional Plans for Intentionally Deviated Wells....................................................................... 5 (Requirements of 20 AAC 25.050(b)) ............. ............. ...... ._........._......................_........................... ....................... .......................... 5 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3S-08CL1 lateral.....................................................................................................6 Attachment 2: Current Well Schematic for 3S-08C.........................................................................................................6 Attachment 3: Proposed Well Schematic for 3S-08CL1 lateral.......................................................................................6 Page 1 of 6 January 14, 2018 PTD Application: 3S-08CL1 Well Name and Classification (Requirements of 20 AAC 25.005(17 and 20 AAC 25.005(b)) The proposed lateral described in this document is 3S-08CL1. The lateral will be classified as "Development - Oil" well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The lateral will target the C sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 3S-08CL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,200 si. Using the maximum formation pressure in the area of 4,447 psi in 3S-07 (i.e. 14.6 ppg , the maximum potential surface pressure in 3S -08C, assuming a gas gradient of 0.1 psi/ft, would be 3,870 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3S -08C was measured to be 1,801 psi (6.0 ppg EMW) on 8/12/2018. The maximum downhole pressure in the 3S -08C vicinity is the 3S-07 at 4,447 psi (14.6 ppg EMW) measured on 4/18/2018. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 3S -08C have injected gas, so there is a possibility of encountering free gas while drilling the 3S-08CL1 lateral. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3S-08CL1 lateral will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3S-08CL1 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 January 14, 2018 PTD Application: 3S-08CL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 3S-08CL1 10690' 13525' 5806' 5811' 2-3/8", 4.7#, L-80, ST -L blank & 33' 108' 1640 670 Surface slotted liner; with swell packer Existing Casing/Liner Information Category OD Weight (ppf)MD Grade Connection Top Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 WELDED 33' 108' 33' 108' 1640 670 Surface 9-5/8" 40 L-80 BTCM 29' 4263' 29' 2661' 5750 3090 Intermediate 7" 26 L-80 BTCM 27' 8795' 27' 5848' 7240 5410 Production 4-1/2" 12.6 L-80 IBTMOD 8188' 12055' 5742' 5872' 8430 7500 Tubing 3-1/2" 9.3 L-80 EUE 8rd MOD 23' 8237' 23' 5761' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AA C 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.4 ppg NaCl/Naar completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3S-08CL1 lateral we will target a constant BHP of 11.4 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 January 14, 2018 PTD Application: 3S-08CL1 Pressure at the 3S-08CL1 Window 10700' MD, 5775' ND Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 3S -08C is a Kuparuk C sand producer equipped with 3-1/2" tubing, 7" intermediate casing, and 4-1/2" production liner. The CTD sidetrack will utilize a single lateral to target the C -sands to the northwest of 3S -08C. The lateral will increase C -sand resource recovery on the sand trend edge. Prior to CTD operations slickline will change out the gas lift valves and service coil will conduct a dummy whipstock drift. Nabors CDR3-AC will run and set a whipstock at 10700' MD. The whipstock will be utilized to cut a window in the 4-1/2" production liner and drill a single lateral. CTD Drill and Complete 3S-08CL1 Lateral: Pre -CTD Work 1. RU Slickline: Change out GLV's. 2. RU Service Coil: Conduct dummy whipstock drift. 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3S-08CL1 Lateral a. Set whipstock at 10700' MD b. Mill 2.80" window at 10700' MD. c. Drill 3" bi-center lateral to TD of 13525' MD. Page 4 of 6 January 14, 2018 Pumps On 1.8 bpm) Pumps Off C -sand Formation Pressure 6.0 1801 psi 1801 psi Mud Hydrostatic 8.6 2582 psi 2582 psi Annular friction i.e. ECD, 0.08psi/ft) 856 psi 0 psi Mud + ECD Combined no chokepressure) 3438 psi Overbalanced -1637psi) 2582 psi Overbalanced -781psi) Target BHP at Window 11.4 3423 psi 3423 psi Choke Pressure Required to Maintain Target BHP 0 psi 841 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 3S -08C is a Kuparuk C sand producer equipped with 3-1/2" tubing, 7" intermediate casing, and 4-1/2" production liner. The CTD sidetrack will utilize a single lateral to target the C -sands to the northwest of 3S -08C. The lateral will increase C -sand resource recovery on the sand trend edge. Prior to CTD operations slickline will change out the gas lift valves and service coil will conduct a dummy whipstock drift. Nabors CDR3-AC will run and set a whipstock at 10700' MD. The whipstock will be utilized to cut a window in the 4-1/2" production liner and drill a single lateral. CTD Drill and Complete 3S-08CL1 Lateral: Pre -CTD Work 1. RU Slickline: Change out GLV's. 2. RU Service Coil: Conduct dummy whipstock drift. 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3S-08CL1 Lateral a. Set whipstock at 10700' MD b. Mill 2.80" window at 10700' MD. c. Drill 3" bi-center lateral to TD of 13525' MD. Page 4 of 6 January 14, 2018 PTD Application: 3S-08CL1 d. Run 2-3/8" blank liner and slotted liner with a swell packer. The top of the liner will be ran back into the 3-1/2" tubing with a deployment sleeve on top. 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running - The 3S-08CL1 lateral will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (6704200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans Page 5 of 6 January 14, 2018 PTD Application: 35-08CL1 - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3S-08CL7 995' - Distance to Nearest Well within Pool Lateral Name Distance Well 3S-08CL1 2920' 3S-21 16. Attachments Attachment 1: Directional Plans for 3S-08CL1 lateral Attachment 2: Current Well Schematic for 3S -08C Attachment 3: Proposed Well Schematic for 3S-08CL1 lateral Page 6 of 6 January 14, 2018 Conoco`Phillips Pro(eot Kuparuk River Unit Site: Kuparuk 35 Pad arowm.ror�.WELLBORE PeseniO Norw.+sss maa FFlea DETAILS' 3S-08CL1 REFERENCE INFORt4RBON PareO[Wellbore: 3"8C coor&nale lure?Rekrerce: wet 3soe, menorm VenicallNDl Rehrzrce: 3 c@M.Nwn (De 141) Well: 3S -DB slreo m: nameanr Tie on MD: 10650.01 sttnao lvsl Rtlee..W-(D.aDN. o.ODE) Wellbore: JS-OBCLi w°ia'°-B0'°� Meawretl0 @Cu Plan: 3S-0BCL1_wp01135.08t3S-0BCL1) r4o DOG"; C&k henna. ium BA ER01 BAT GE comps +Sfil3/t4Flt 3tifill/}ihll 63001 56001 �Dno 4900 al u 4200 � 3� Q op + iy 3500 x vecp 1 1 .-GI - a/ 2800 -- /rn0 2100 — +s.Rr3cr'n ;mr _ JI F I, c v 1400. a 7001 +Ye ti lyl6 I � c 11 � vm,umr — .700 N `: IN 51( 11 NC,c1/xR i-.-1400 2100 c - o -3500 0 r 1 O N 4200 ___ 1__ F. -0900 - _ ♦ ut + 1114i I - -5600 -6300 -7000 .7700 - 6 _ �1 o -8400 _ __ _ JpNO enc) L -9800 i -11900-11200-10500-9000 -9100 -8400 -7700 -7000 -6300 -5600 4900 -4200 -3500 -2800 -2100 -1400 -700 0 700 1400 2100 2800 3500 4200 4900 56W 6300 70100 7700 8400 9100 9800 10500 11200 West( -)Bast(+) (700 usft/in) 3S -08C @ 55.20us11(Doyon 141) ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 3S Pad 3S-08 3S-08CL1 Plan: 3S-08CL1_wp01 Standard Planning Report 11 January, 2019 BT�a GHES GE company ConocoPhillips BA° ICER ConocoPhillips Planning Report �jUGHES aGEcompany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 3S Pad Well: 3S-08 Wellbore: 3S-08CL7 Design: 3S-08CL1_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3S-08 Mean Sea Level 38-08C @ 55.20usft (Doyon 141) True Minimum Curvature Project Kuparuk River Unit. North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor She Kuparuk 3S Pad 70" 23'40.307 N Longitude: 150' 11' 34.034 W Site Position: Northing: 5,993,843.00usft Latitude: 70° 23'39.520 N From: Map Easting: 476,455.00usft Longitude: 150° 11' 29.646 W Position Uncertainty: 0.00 usft Slot Radius: 0.000m Grid Convergence: -0.18 " Wen 3S -O8 Well Position +N/S +E/ -W Position Uncertainty Wellbore 3S-08CL1 Magnetics Model Name BGGM2018 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Design Audit Notes: Version: Vertical Section: an Sections 3S-08CL1 wp01 Sample Date 4/1/2019 5,993,923.52 usft 476,305.45 usft 27.50 usft Latitude: 70" 23'40.307 N Longitude: 150' 11' 34.034 W Ground Level: 27.70 usft _ 80.87 Build Turn Declination V) Dip Angle (°) 300.00 16.55.. _ 80.87 Build Phase: PLAN Tie On Depth: Depth From (TVD) +NIS +E/ -W (usft) (usft) (usft) -27.70 0.00 0.00 Field Strength (nT) 57,414 10,650.01 Direction 300.00 -� Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) V) (I (usft) (usft) (usft) ('/100usft) (°/100usft) (°/100usft) (°) 10,650.01 90.41 241.87 5,806.35 -4,267.65 1,154,47 0.00 0.00 0.00 0.00 10,700.00 91.43 239.51 5,805.55 4,292.11 1,110.89 5.14 2.04 4.72 -66.61 10,720.00 89.03 239.51 5,805.47 -4,302.26 1,093.66 12.00 -12.00 0.00 180.00 10,750.00 87.55 241.00 5,806.36 -4,317.14 1,067.63 7.00 4.95 4.95 135.00 10,780.00 87.55 243.10 5,807.65 4,331.19 1,041.15 7.00 0.01 7.01 90.00 10,830.00 90.02 245.57 5,808.71 4,352.83 996.10 7.00 4.95 4.95 45.00 11,230.00 90.49 273.57 5,806.88 4,424.53 606.62 7.00 0.12 7.00 89.00 11,620.00 90.44 300.87 5,803.67 4,310.17 237.62 7.00 -0.01 7.00 90.00 12,020.00 88.04 328.77 5,809.09 4,031.06 -43.28 7.00 -0.60 6.98 95.00 12,350.00 90.55 305.80 5,813.22 -3,790.25 -265.61 7.00 0.76 -6.96 276.00 12,750.00 90.01 333.80 5,811.23 -3,487.76 -521.22 7.00 -0.13 7.00 91.00 13,000.00 90.01 316.30 5,811.18 -3,283.65 -663.88 7.00 0.00 -7.00 270.00 13,325.00 90.01 339.05 5,811.11 -3,010.81 -836.53 7.00 0.00 7.00 90.00 13,525.00 90.01 325.05 5,811.07 -2,834.58 -930.03 7.00 0.00 -7.00 270.00 Target 1/1112019 3:54 11 PM Page 2 COMPASS 5000.14 Build 85D 1/11/2019 3:54:11PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA�CER ConocoPhillips Planning Report UGHES a GEmanpany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 35-08 Company _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3S -08C @ 55.20usft (Doyon 141) Site: Kuparuk 3S Pad North Reference: True Well: 35-08 Survey Calculation Method: Minimum Curvature Wellbore: 38-08CL1 Vertical Design: 3S-08CL1_wp01 Toolface Map 1/11/2019 3:54:11PM Page 3 COMPASS 5000.14 Build 85D Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/S +E/ -W Section Rate Azimuth Northing Easting (usft) V) (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 10,650.01 90.41 241.87 5,806.35 -0,267.65 1,154.47 -3,133.63 0.00 0.00 5,989,652.66 477,446.28 TIP 10,700.00 91.43 239.51 5,805.55 -4,292.11 1,110.89 -3,108.12 5.14 -66.61 5,989,628.33 477,402.62 KOP 10,720.00 89.03 239.51 5,805.47 4,302.26 1,093.66 -3,098.27 12.00 -180.00 5,989,618.24 477,385.36 End 12 chs, Start 7 dls 10,750.00 87.55 241.00 5,806.36 -4,317.14 1,067.63 -3,083.16 7.00 135.00 5,989,603.45 477,359.28 4 10,780.00 87.55 243.10 5,807.65 4,331.19 1,041.15 -3,067.26 7.00 90.00 5,989,589.49 477,332.77 8 10,800.00 88.54 244.09 5,808.33 4,340.08 1,023.25 -3,056.20 7.00 45.00 5,989,580.65 477,314.84 10,830.00 90.02 245.57 5,808.71 4,352.83 996.10 -3,039.07 7.00 44.97 5,989,567.98 477,287.65 6 10,900.00 90.11 250.47 5,808.63 4,379.02 931.21 -2,995.96 7.00 89.00 5,989,542.00 477,222.68 11,000.00 90.23 257.47 5,808.33 4,406.62 835.16 -2,926.58 7.00 89.01 5,989,514.71 477,126.55 11,100.00 90.35 264.47 5,807.83 4,422.30 736.46 -2,848.94 7.00 89.03 5,989,499.34 477,027.81 11,200.00 90.46 271.47 5,807.13 4,425.85 636.59 -2,764.22 7.00 89.06 5,989,496.12 476,927.94 11,230.00 90.49 273.57 5,806.88 -4,424.53 606.62 -2,737.61 7.00 89.11 5,989,497.53 476,897.98 7 11,300.00 90.49 278.47 5,806.28 -4,417.19 537.03 -2,673.67 7.00 90.00 5,989,505.09 476,828.42 11,400.00 90.48 285.47 5,805.43 4,396.47 439.27 -2,578.65 7.00 90.04 5,989,526.12 476,730.73 11,500.00 90.46 292.47 5,804.61 4,363.98 344.76 -2,480.56 7.00 90.10 5,989,558.90 476,636.34 11,600.00 90.44 299.47 5,803.82 4,320.22 254.91 -2,380.87 7.00 90.16 5,989,602.94 476,546.64 11,620.00 90.44 300.87 5,803.67 -4,310.17 237.62 -2,360.87 7.00 90.21 5,989,613.05 476,529.39 8 11,700.00 89.95 306.45 5,803.40 4,265.85 171.06 -2,281.07 7.00 95.00 5,989,657.58 476,462.97 11,800.00 89.34 313.42 5,804.03 4,201.70 94.43 -2,182.63 7.00 95.02 5,989,721.96 476,386.56 11,900.00 88.74 320.40 5,805.71 4,128.73 26.17 -2,087.03 7.00 94.97 5,989,795.14 476,318.53 12,000.00 88.15 327.38 5,808.43 4,048.02 -32.71 -1,995.68 7.00 94.86 5,989,876.02 476,259.91 12,020.00 68.04 328.77 5,809.09 4,031.06 -43.28 -1,978.05 7.00 94.67 5,989,893.02 476,249.40 9 12,100.00 88.63 323.20 5,811.42 -3,964.80 -88.00 -1,906.19 7.00 -84.00 5,989,959.41 476,204.90 12,200.00 89.39 316.24 5,813.14 -3,888.57 -152.60 -1,812.13 7.00 -83.84 5,990,035.84 476,140.54 12,300.00 90.16 309.28 5,813.53 -3,820.72 -225.97 -1,714.66 7.00 -83.72 5,990,103.92 476,067.39 12,350.00 90.55 305.80 5,813.22 -3,790.25 -265.61 -1,665.10 7.00 -83.69 5,990,134.50 476,027.86 10 12,400.00 90.48 309.30 5,812.77 -3,759.78 -305.24 -1,615.55 7.00 91.00 5,990,165.10 475,988.32 12,500.00 90.35 316.30 5,812.04 -3,691.88 -378.56 -1,518.10 7.00 91.03 5,990,233.22 475,915.23 12,600.00 90.22 323.30 5,811.54 -3,615.55 -443.06 -1,424.07 7.00 91.08 5,990,309.75 475,850.97 12,700.00 90.08 330.30 5,811.27 -3,531.92 -497.78 -1,334.87 7.00 91.12 5,990,393.54 475,796.52 12,750.00 90.01 333.80 5,811.23 -3,487.76 -521.22 -1,292.49 7.00 91.14 5,990,437.77 475,773.23 11 12,800.00 90.01 330.30 5,811.22 -3,443.80 -544.65 -1,250.12 7.00 -90.00 5,990,482.01 475,749.94 12,900.00 90.01 323.30 5,811.20 -3,359.98 -599.37 -1,160.92 7.00 -90.00 5,990,565.79 475,695.49 13,000.00 90.01 316.30 5,811.18 -3,283.65 -663.88 -1,066.89 7.00 -90.00 5,990,642.32 475,631.23 12 13,100.00 90.01 323.30 5,811.16 -3,207.31 -728.38 -972.86 7.00 90.00 5,990,718.85 475,566.98 13,200.00 90.01 330.30 5,811.14 -3,123.69 -783.11 -883.65 7.00 90.00 5,990,802.64 475,512.52 13,300.00 90.01 337.30 5,811.12 -3,034.02 -827.23 -800.61 7.00 90.00 5,990,892.44 475,468.69 13,325.00 90.01 339.05 5,811.11 -3,010.81 -836.53 -780.95 7.00 90.00 5,990,915.67 475,459.47 13 13,400.00 90.01 333.80 5,811.10 -2,942.10 -866.51 -720.63 7.00 -90.00 5,990,984.48 475,429.70 1/11/2019 3:54:11PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillipsBAKER ConocoPhillips Planning Report UGHES aGEmmpany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 3S Pad Well: 3S-08 Wellborn: 3S-08CL1 Design: 3S-OSCL1 wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3S -O8 Mean Sea Level 3S -08C (off 55.20usft (Doyon 141) True Minimum Curvature Planned Survey Vertical Casing Hole Depth Target Name Diameter Diameter Measured TVD Below -hit/miss target Dip Angle Dip Dir. TVD Vertical Dogleg Toolface Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing (usft) (_) (1 (usft) (usft) (usft) (usft) (°/l00usft) V) (usft) 13,500.00 90.01 326.80 5,811.08 -2,855.29 -916.03 -634.34 7.00 -90.00 5991,071.43 13,525.00 90.01 325.05 5,81107 -2,834.58 -930.03 -611.86 7.00 -90.00 5,991,092.18 Planned TO at 1362600 0.00 5,989,503.48 Point 0.00 -154.63 -499.55 5,989,350.45 Targets Vertical Casing Hole Depth Target Name Diameter Diameter (usft) (usft) Name -hit/miss target Dip Angle Dip Dir. TVD +NIS +E/ -W Northing -Shape (I V) (usft) (usft) (usft) (usft) 3S-08CL1_T03 0.00 0.00 5,811.00 -2,834.25 -930.73 5,991,092.52 - plan misses target center by 0.78usft at 13525.00usft MD (5811.07 TVD, -2834.58 N, -930.03 E) - Point 3S-08 CTD Polygon 0.00 0.00 0.00 -4,416.77 1,179.47 5,989,503.48 - plan misses target center by 5807.23usft at 10720.00usft MD (5805.47 TVD, -4302.26 N, 1093.66 E) - Polygon Point 1 0.00 0.00 0.00 5,989,503.48 Point 0.00 -154.63 -499.55 5,989,350.45 Point 3 0.00 -51.69 -832.92 5,989,454.43 Point 0.00 197.04 -1,236.76 5,989,704.42 Points 0.00 1,645.47 -2,707.23 5,991,357.34 Point 0.00 2,118.78 -2,000.03 5,991,628.38 Point 0.00 677.90 -675.25 5,990,183.45 Point 8 0.00 333.68 200.95 5,989,836.49 Point 0.00 0.00 0.00 5,989,503.48 3S-08CL1_T01 0.00 0.00 5,809.00 -4,353.34 996.25 5,989,567.48 - plan misses target center by 0.59usft at 10830.05usft MD (5808.71 TVD, -4352.86 N, 996.05 E) - Point 3S-08CL1 T02 0.00 0.00 5,803.00 -4,265.92 170.88 5,989,657.50 - plan misses target center by 0.43usft at 11700.09usft MD (5803.40 TVD, -4265.79 N, 170.99 E) - Point Casing Points Map Easting (usft) 475,380.47 475,366.53 Easting (usft) Latitude Longitude 475,365.83 70' 23' 12.432 N 150° 12' 1.282 W 477,470.79 70" 22'56.868 N 150° 10'59.510 W 477,470.79 476,970.81 476,637.80 476,234.79 474,769.70 475,477.69 476,797.76 477,672.78 477,470.79 477,287.80 70" 22'57.492 N 150° 11'4.873 W 476,462.79 70° 22'58.352 N 150' 11'29.032 W Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 13,525.00 5,811.08 23/8" 2.375 3.000 1/1112019 3.54.11PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BA_ jCER ConocoPhillips Planning Report UG,ES a GE.anpany Database: Company: Project. Site: Well: Wellbore: Design: Plan Annotations EDT 14 Alaska Production _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 3S Pad 35-08 3S-08CLI 3S-OSCL1_wp01 Measured Vertical +El -W Depth Depth -4,267.65 (usft) (usft) 1,110.89 10,650.01 5,806.35 -4,317.14 10,700.00 5,805.55 1,041.15 10,720.00 5,805.47 -4,424.53 10,750.00 5,806.36 237.62 10,780.00 5,807.65 -3,790.25 10,830.00 5,808.71 -521.22 11,230.00 5,806.88 -3,010.81 11,620.00 5,803.67 -930.03 12,020.00 5,809.09 12,350.00 5,813.22 12,750.00 5,811.23 13,000.00 5,811.18 13,325.00 5,811.11 13,525.00 5,811.07 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method - Local Coordinates -NI-S +El -W (usft) (usft) -4,267.65 1,154.47 -4,292.11 1,110.89 -4,302.26 1,093.66 -4,317.14 1,067.63 -4,331.19 1,041.15 4,352.83 996.10 -4,424.53 606.62 -4,310.17 237.62 -4,031.06 -43.28 -3,790.25 -265.61 -3,487.76 -521.22 -3,283.65 -663.88 -3,010.81 -836.53 -2,834.58 -930.03 Comment TIP KOP End 12 dls, Start 7 dls 4 5 6 7 8 9 10 11 12 13 Planned TD at 13525.00 Well 35-08 Mean Sea Level 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature 1/11/2019 3.54:11PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillipsB�(ER ConocoPhillips Travelling Cylinder Report UGHES aGEcompany Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3S Pad She Error: 0.00 usft Reference Well: 3S-08 Well Error: 0.00 usft Reference Wellbore 3S-08CL1 Reference Design: 3S-08CL1_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3S -O8 3S -08C @ 55.20usft (Doyon 141) 3S -08C @ 55.20usft (Doyon 141) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 3S-08CL1_wp01 Need Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria To Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,650.01 to 13,525.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,549.75 usft Error Surface: Pedal Curve Survey Tool Program Date 1/11/2019 Need Allowable Warning From To -CB -GYRO -SS , Reference (usft) (usft) Survey (Wellbore) Tool Name Description 85.90 85.90 3S-08 CB -GYRO -SS (3S-08) CB -GYRO -SS Camera based gyro single shot 194.59 4,207.48 3S-08IFR (3S-08) MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,262.50 8,780.39 3S -08C IIFR+MS+SAG Halliburton (38-08 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,823.57 10,650.01 3S -08C IIFR+MS(3S-08C) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,650.01 13,525.00 3S-08CL1_wp01 (3S-OSCL1) MWD MWD - Standard Casing Points 7.85 A imutb aN/S Measured Vertical 10,968.22 Casing Hole 34.94 Depth Depth 23.87 Pass- Major Risk Diameter Diameter 11) (usft) (usftl Name (in) (in) 5,861.26 8,795.00 5,847.71 7" 5.881.26 7.000 8,750 0.06 13,525.00 5,866.27 23/8" -4,279.65 2.375 3.000 Summary Kuparuk 3S Pad - 3S-08 - 3S -08C - 3S-080 Need Allowable Warning Survey Program'. 36 -CB -GYRO -SS , Reference Offset Centre to No -Go Allowable Onset Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Depth (usft) Kuparuk 3S Pad Depth 3.750 7.85 A imutb aN/S 3S-08 - 3S -08C - 3S -08C 10,968.22 10,975.00 34.94 11.08 23.87 Pass- Major Risk Offset Design Kuparuk 3S Pad - 3S-08 - 3S -08C - 3S-080 Need Allowable Warning Survey Program'. 36 -CB -GYRO -SS , 195-MWDMFR-AK-CA2-6C, 4263.MWUMFR-AK-CAZ-So, 8024MWDHFR-AK-CAZ-SC (usft Rererena Onset 000 Semi Major Axis -0.84 FAIL - Major Risk 3750 0,00 1,84 Measured vertical Measured Vertical Reverence Offset T..Iface+ onset Wellbore Centre Depth O."It Depth Depth 3.750 7.85 A imutb aN/S +kew (deft) (den) (Malt) lusel (Man) (urn! 11) (usft) (usft) 1067500 5,861.26 10.67500 5.881.26 0.13 0.06 83.19 -4,279.65 1,132.56 10,70000 5.860.75 10)00.00 5.Rx.75 0.27 0.13 81,98 4,292.11 1,11089 10,724.97 5,86026 10,725.00 5,860.02 0.45 0.19 -140.24 4,305.m 1,089,49 10,749.84 5,861.56 10,750.00 5.859.09 0.63 0,25 -148.27 4,318.32 1,06835 10,,44.61 5,88282 10,775.00 5.858.37 0.83 0,32 -153,97 4,331+65 1,047.21 10,799.47 5,863.52 10.800.00 5.857.96 1.00 0.38 -160.75 4,344,89 1,028,01 10,824.30 5,863.90 10.825.00 5.857.87 1.25 0,45 -168.83 -4,358.04 1004.75 10,848.85 5,883.90 10,850.00 5.850.08 1.48 0,51 .171+57 4,371.10 903.43 10,873.12 5,863.87 10.575.00 5,858.52 1.72 0.58 177.65 -4,384.05 982.05 io,897.tg 5,883.83 10,900.00 5.859.18 1.97 0,65 173.41 4,396.91 940.62 10.920.99 5.863]8 10,925.00 5,860.02 2.23 0,72 170,46 -4,40986 919.13 Rule Assigned: Major Risk Onset site Ed. O.00 u91 Offset Well EDer: 0.00 .it Casing- Centre to Need Allowable Warning Hole arse Centre Distance Carnation (Ia) (usft) (usft ansa) 3750 000 109 -0.84 FAIL - Major Risk 3750 0,00 1,84 430 FAIL - Major Risk 3,750 0.79 274 -0.83 FAIL - Major Risk 3.750 2.83 3.62 0.44 Pass - Major Risk 3.750 5.31 4.50 2.06 Pass - Major Risk 3.750 7.85 5.38 3.57 Pass -Major Risk 3.750 10.28 6.28 4.82 Pass -Major Risk 3.750 12.98 7.15 6.36 Paso -Major Risk 3,750 16.40 8.01 8.70 Pass -Major Risk 3.750 20.54 8.82 11.90 Pass -Major Risk 3.750 25.39 9.61 15.86 Pass -Major Risk 10.944.60 5,863.72 10.950.00 5.861.05 2.50 0.80 least -4,421.94 897.38 3.750 30.52 10.36 20.19 Pass -Major Risk 10,968.22 5,863.65 10,975.00 5,852.14 2.79 0.88 16732 -4,132.87 874.93 3,750 34.94 IiSa 23.87 Pass- Major Risk, CC, ES, SF CC - Min centre to center distance or covement paint. SF - min seoaration factor. ES - min ellipse seoaradon 111112019 2:32:54PM Page 2 COMPASS 5000.14 Build 85D 101, ConocoPhiiip5 Project: Kupamk River Unk Site: Kupamk 3S Pad 4alaun.mrN. xenn u.1. mono-. ias• w9mNe rasa WELLBORE DETAILS: 35ABCL1 REFERENCE INFORWTION Parent Wellbore: 3S -OBC C� Jinae INET Reemae: Wein .rive Nwn Wali: 3S,08 Tie on MD: 10650.01 veael Rw,enm: uwn sw (erol Mal Wellbore: 3S.OSCL1 uyo gy:mn• Northing Iva)of wfiner. Plan: 9S-0SCLt_wpOt (3541a/3SeaCLtj au; 4nrm+ wmr. ecwam+ Longitude C@55Xaft l0oyon lap ..d Reeanee: ssaec R wmwea 5993923.52 476305.45 nvaw cwueeon wmoa: wimum omeme hla Mean E 900 450 0 -45C -90f c -13s( 3 O-I80f a �zzs( ±, !-270( 0 x-360( N 405( 450( -495f -540( BAKER I�VGHE 11 a." WELL DETAILS: 3S-08 +N/ -S +E/ -W Northing Fasting Latitude Longitude 0.00 0.00 5993923.52 476305.45 70° 23 40.307 N 150° 11'34.034 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 10650.01 90.41 241.87 5806.35 -4267.65 1154.47 0.00 0.00 -3133.63 TIP 2 10700.00 91.43 239.51 5805.55 -4292.11 1110.89 5.14 -66.61 -3108.12 KOP 3 10720.00 89.03 239.51 5805.47 -0302.26 1093.66 12.00 180.00 -3098.27 End 12 cls, Start 7 dls 4 10750.00 87.55 241.00 5806.36 -0317.14 1067.63 7.00 135.00 -3083.16 4 5 10780.00 87.55 243.10 5807.65 -0331.19 1041.15 7.00 90.00 -3067.26 5 6 10830.00 90.02 245.57 5808.71 -4352.83 996.10 7.00 45.00 -3039.07 6 7 11230.00 90.49 273.57 5806.88 -4424.53 606.62 7.00 89.00 -2737.61 7 8 11620.00 90.44 300.87 5803.67 -4310.17 237.62 7.00 90.00 -2360.87 8 9 12020.00 88.04 328.77 5809.09 -4031.06 -43.28 7.00 95.00 -1978.05 9 10 12350.00 90.55 305.80 5813.22 -3790.25 -265.61 7.00 276.00 -1665.10 10 11 12750.00 90.01 333.80 5811.23 -3487.76 -521.22 7.00 91.00 -1292.49 11 12 13000.00 90.01 316.30 5811.18 -3283.65 •663.88 7.00 270.00 -1066.89 12 13 13325.00 90.01 339.05 5811.11 -3010.81 -636.53 7.00 90.00 -780.95 13 14 13525.00 90.01 325.05 5811.07 -2834.58 -930.03 7.00 270.00 -311.86 Planned TD at 13525. Mean E 900 450 0 -45C -90f c -13s( 3 O-I80f a �zzs( ±, !-270( 0 x-360( N 405( 450( -495f -540( BAKER I�VGHE 11 a." 0 0 0 0 0 0 0 o V o o e e o 0 0 0 West( -)Bast(+) (450 usft/in) 480 4950 3 -0BnS 3 .0811 T03 3s Dans sa - 5100 3S MS SA 1 I leen TDMI3525. 3S-0 LI_ ,OB LI T( 1 U ' tz 10 5250 ] 6. 5:4 ....... . ... .. TI KOP 5400 E x] 12d s, Stan]dls SS-08C SSSO 0 0 0 0 0 0 0 o V o o e e o 0 0 0 West( -)Bast(+) (450 usft/in) Vertical Section at 300.00° (150 us8/in) 480 4950 - 5100 1 I U 5250 5400 SSSO -0Bn 034` Planne 3 To 1352500 S- 8135- BCCI 5]00 ., .. .... 85 P ..... P " 0 6 7 & 0 11 2 1 600 -08n B End 12 dls, SU rt]dl 3S -C Y3S 6150 - - - - - o S o S o S o 8 0 0 0 0 0 0 0 = 0 0 0 0 0 0 8 0 0 0 Vertical Section at 300.00° (150 us8/in) 16" 62# H-40 shoe @108'MD 9-5/8" 40# L-80 shoe @ 4263' MD 3S -08C Proposed CTD Schematic 3-1/2" Camco DS Nipple @ 502' RKB (2.875" ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing from surface to 8237' RKB 3-1/2" Camco KBMG gas lift mandrels @ 4589', 5774', 6646', 7360', & 8138' RKB 3-1/2" Camco DS Nipple @ 8186' RKB (2.812" ID) 4-1/2" 12.6# L-80 EUE 8rd Tubing from 8188 to 12055' RKB 5" locator sub @ 8196' RKB Liner too Baker 5" x 7" ZXP liner top packer @ 8188' RKB Baker 5" x 7" Flex -Lock liner hanger @ 8211' RKB Baker 80-40 SBE @ 8221' RKB XO Bushing @ 8241' RKB 7" 26.4# L-80 shoe @ 8795' MD KOP A 10 700' MD 4-1/2" 12.6# L-80 shoe Pert Pups w/ qty. 6 - 1/2" holes @ 12,055' RKB Solid Liner - Nipple Profile - Solid Liner - Swell Packer 3S-OSCL1 wp01 TD @ 13,525' MD Boyer, David L (DOA) From: Ohlinger, James 1 <James.J.Ohlinger@conocophillips.com> Sent: Thursday, January 17, 2019 3:25 PM To: Boyer, David L (DOA) Subject: KRU 3S-08CL1 H2S Potential Here is the last measurements from 3S pad Yes, normal rig H2S monitoring equipment will be sufficient for 3S. Well 3S-03 2 -Nov -18 90 3S-07 24 -Jan -17 55 3S-088 1 -Feb -07 80 3S -08C 22 -May -18 90 3S-10 10 -Oct -15 170 3S-15 26 -Sep -14 100 3S-18 28Jun-17 70 3S-19 6Jun-18 90 3S-23 7 -Dec -05 55 3S -23A 2 -Oct -18 80 3S-24 28 -Dec -03 75 3S -24A 16 -Now -15 75 3S-613 1 -Aug -16 45 3S-620 15 -Dec -18 60 From: Boyer, David L (DOA) <david. boyer2@a laska.gov> Sent: Thursday, January 17, 2019 3:13 PM To: Ohlinger, James 1 <James.J.Ohlinger@conocophillips.com> Subject: [EXTERNAL]KRU 3S-08CL1 H2S Potential James, Steve Davies is on vacation and has a list of Kuparuk pads (most) that require H2S measures on the PTD. 3S Pad is not on that list. Has H2S been detected on the pad, since Kuparuk is a mature field with waterflood? Otherwise, normal rig H2S monitoring equipment would be sufficient for 3S. Thanks, Dave Boyer AOGCC TRANSMITTAL LETTER CHECKLIST WELL NAME: IAC R (.l '� S —" O g G L Z PTD: �„ 19 R V Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: aK U POOL:KA.4�d.Y t1_J Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. 0AnJ. J63 , API No. 50-_L 03-2 pgs0 -_Q3 _r2 ✓ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _-_) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throw h taret zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Companv Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Namel must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of J well logs to be run. In addition to the well logging program proposed by V/ (Companv Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements LI/ Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 PTD#:2190080 Company CONOCO PHILLIPS ALASKA INC Initial Classrrype Well Name: KUPARUK RIV UNIT 3S-08CL1 Program DEV Well bore seg DEV /_PPEND GeoArea 890 Unit 11160 On/Off Shore On—_.— Annular Disposal ❑ Administration 1 Permit fee attached_. _.. _..... __._ NA. _.._--.. __.. __............................... ... 2 Lease number appropriate ...................... Yes ----... ............----------------- --------------- 3 Unique well name and number. ----- -- - Yes _ ----- ------------ - _ _ _ 4 Well located in a. defined pool....... _ _ _ _ Yes .. ............. 5 Well located proper distance from drilling unit boundary_ Yes --------------------------- 6 Well located proper distance from other wells. Yes 7 Sufficient acreageavailable in drilling unit_ _ _ _ _ _ _ _ _ ... ..... Yes 8 If deviated, is wellbore plat. included _ _ _ _ _ _ _ _ _ _ _ _ Yes Directional plan view and spider map are provided. 9 Operator only affected party- _ _ _ _ _ _ Yes ......... 10 Operator has appropriate bond in force _ ....... Yes 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 12 Permitcan be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait _ _ _ _ _ _ _ _ Yes DLB 1/17/2019 14 Well located within area and strata authorized by Injection Order # (put. 10# in comments) (For_ NA _ 15 All wells within 1/4 mile area of review identified (For service well only) _ NA 16 Pre -produced injector; duration of pre production less than 3 months (For service well only) NA. 17 Nonconven. gas conforms to AS31,05:030Q.1 A),Q,2.A-D) _ _ _ NA 18 Conductor string provided _ _ . . . ...................... .. NA. Conductor set. for KRU 3S-08 Engineering 19 Surface casing protects all known USDWs _ _ .. NA _ Surface casing set for KRU 3S-08 20 CMT vol adequate. to circulateon conductor & surf csg _ _ _ _ _ _ _ NA .... Surface casing set and fully cemented 21 CMT_vol adequate. to tie-in long string to surf rag _ _ NA 22 CMT Oil rover all known productive horizons _ _ _ _ _ _ _ _ _ _ _ ____ _ No..... _ Productive interval Oil be completed with. an.unoemented slotted liner 23 Casing designs adequate for C. T, B &, permafrost _ _ _ _ _ _ _ _ _ _ _ Yes 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ _ Yes _ _ _ Rig has steel tanks; all waste to approved disposal wells_ _ 25 If a. re -drill, has 10-403 fol abandonment been approved _ ... _ _ NA 26 Adequate wellbore separation proposed _ _ _ _ _ _ Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations. _ _ _ _ _ _ _ _ NA Appr Date 28 Drilling fluid. program schematic & equip list adequate. _ _ Yes Max formation pressure is 4447 psig(14.6 ppg EMW); will drill, w/ 8,6. ppg EMW and maintain overbal w/ MPD VTL 1/18/2019 29 BOPEs, do they meet. regulation _ _ _ _ _ Yes ...... _ ........ .. _ _ _ _ 30 BOPE.press rating appropriate; test to (put psig in comments).. _ _ _ _ _ _ _ _ Yes MPSP is 3870 psig; will test BOPs_to 4200 prig 31 Choke manifold complies w/API. RP -53 (May 84)... .. .... Yes 32 Work will occur without operation shutdown. _ _ _ _ _ _ _ _ _ _ _ Yes 33 Is presence of H2S gas probable _ _____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 1-12S measures required... 34 Mechanical condition of wells within AOR verged (For service well only) _ _ _ _ _ _ _ _ _ NA_ 35 Permit. can be issued w/o hydrogen sulfide measures _ _ _ ..... - ...... No.. _ _ _ On 05/22/18, 90 ppm was. measured in 3S -08C.. This is consistent. Geology 36 Data presented on potential overpressure zones . . . . . . . . . . . . ............ Yes ..... with. H2S, values from other Kuparuk pads where measures have been required.. Appr Date 37 Seismic analysis of shallow gas.zones.. .. _ _ . NA_ DLB 1/17/2019 38 Seabed condition survey (if off -shore) ............ . _ _ _ _ _ _ _ .. _ _ NA 39 Contact name/phone for weekly_ progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date